integrated resource plan public advisory groupjul 06, 2017 · retirement plan and process ......
TRANSCRIPT
Integrated Resource Plan Public Advisory Group
Meeting 3 ndash July 6 2017
Operational ConsiderationsSystem Operations Existing Conventional ResourcesTransmission and Distribution
bull Welcome and Introduction bull Public Advisory Process and Meeting Schedule bull Operational ConsiderationsRequirements for Future Resources
ndash Assessment of need for additional resourcesbull System Operations Import Limits and Balancing bull Existing Conventional Resources and System Generation
Retirement Plan and Processbull Transmission amp Distribution Systems Overview and Projects bull Discussion
Meeting Agenda
2 EPE Proprietary Material
bull Maritza Perez NM IRP Case Managerbull Omar Gallegos Director of Resource Planning and Managementbull Dave Hawkins VP - System Operations Resource Planning amp
Managementbull Andy Ramirez VP - Power Generationbull Clay Doyle VP - Transmission amp Distribution and System Planningbull Myra Segal Facilitator
Welcome and IntroductionPresenters for this Meeting
3 EPE Proprietary Material
bull Fire Escape Routes
bull Please sign in You will be added to our PAG distribution listndash Skype participants can email NMIRPepelectriccom
bull Facilities
bull Recording of Meetings
bull Terms Glossary
Safety and Basics
4 EPE Proprietary Material
Certain matters discussed in this Integrated Resource Plan (IRP) public advisory group presentation other than statements of historical information are forward-looking statements made pursuant to the safe harbor provisions of the Section 27A of the Securities Act of 1933 as amended and Section 21E of the Securities Exchange Act of 1934 as amended Such statements are subject to a variety of risks uncertainties and other factors most of which are beyond El Paso Electric Companys (EPE or the Company) control and many of which could have a significant impact on the Companys operations results of operations and financial condition and could cause actual results to differ materially from those anticipated Additional information concerning factors that could cause actual results to differ materially from those expressed in forward-looking statements is contained in EPEs most recently filed periodic reports Any such forward-looking statement is qualified by reference to these risks and factors EPE cautions that these risks and factors are not exclusive
Management cautions against putting undue reliance on forward-looking statements or projecting any future assumptions based on such statements Forward-looking statements speak only as of the date of this IRP public advisory group presentation and EPE does not undertake to update any forward-looking statement contained herein except to the extent the events or circumstances constitute material changes in this IRP that are required to be reported to the New Mexico Public Regulation Commission (NMPRC or Commission) pursuant to its IRP Rule 1773 New Mexico Administrative Code
Safe Harbor Statement
5 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Welcome and Introduction bull Public Advisory Process and Meeting Schedule bull Operational ConsiderationsRequirements for Future Resources
ndash Assessment of need for additional resourcesbull System Operations Import Limits and Balancing bull Existing Conventional Resources and System Generation
Retirement Plan and Processbull Transmission amp Distribution Systems Overview and Projects bull Discussion
Meeting Agenda
2 EPE Proprietary Material
bull Maritza Perez NM IRP Case Managerbull Omar Gallegos Director of Resource Planning and Managementbull Dave Hawkins VP - System Operations Resource Planning amp
Managementbull Andy Ramirez VP - Power Generationbull Clay Doyle VP - Transmission amp Distribution and System Planningbull Myra Segal Facilitator
Welcome and IntroductionPresenters for this Meeting
3 EPE Proprietary Material
bull Fire Escape Routes
bull Please sign in You will be added to our PAG distribution listndash Skype participants can email NMIRPepelectriccom
bull Facilities
bull Recording of Meetings
bull Terms Glossary
Safety and Basics
4 EPE Proprietary Material
Certain matters discussed in this Integrated Resource Plan (IRP) public advisory group presentation other than statements of historical information are forward-looking statements made pursuant to the safe harbor provisions of the Section 27A of the Securities Act of 1933 as amended and Section 21E of the Securities Exchange Act of 1934 as amended Such statements are subject to a variety of risks uncertainties and other factors most of which are beyond El Paso Electric Companys (EPE or the Company) control and many of which could have a significant impact on the Companys operations results of operations and financial condition and could cause actual results to differ materially from those anticipated Additional information concerning factors that could cause actual results to differ materially from those expressed in forward-looking statements is contained in EPEs most recently filed periodic reports Any such forward-looking statement is qualified by reference to these risks and factors EPE cautions that these risks and factors are not exclusive
Management cautions against putting undue reliance on forward-looking statements or projecting any future assumptions based on such statements Forward-looking statements speak only as of the date of this IRP public advisory group presentation and EPE does not undertake to update any forward-looking statement contained herein except to the extent the events or circumstances constitute material changes in this IRP that are required to be reported to the New Mexico Public Regulation Commission (NMPRC or Commission) pursuant to its IRP Rule 1773 New Mexico Administrative Code
Safe Harbor Statement
5 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Maritza Perez NM IRP Case Managerbull Omar Gallegos Director of Resource Planning and Managementbull Dave Hawkins VP - System Operations Resource Planning amp
Managementbull Andy Ramirez VP - Power Generationbull Clay Doyle VP - Transmission amp Distribution and System Planningbull Myra Segal Facilitator
Welcome and IntroductionPresenters for this Meeting
3 EPE Proprietary Material
bull Fire Escape Routes
bull Please sign in You will be added to our PAG distribution listndash Skype participants can email NMIRPepelectriccom
bull Facilities
bull Recording of Meetings
bull Terms Glossary
Safety and Basics
4 EPE Proprietary Material
Certain matters discussed in this Integrated Resource Plan (IRP) public advisory group presentation other than statements of historical information are forward-looking statements made pursuant to the safe harbor provisions of the Section 27A of the Securities Act of 1933 as amended and Section 21E of the Securities Exchange Act of 1934 as amended Such statements are subject to a variety of risks uncertainties and other factors most of which are beyond El Paso Electric Companys (EPE or the Company) control and many of which could have a significant impact on the Companys operations results of operations and financial condition and could cause actual results to differ materially from those anticipated Additional information concerning factors that could cause actual results to differ materially from those expressed in forward-looking statements is contained in EPEs most recently filed periodic reports Any such forward-looking statement is qualified by reference to these risks and factors EPE cautions that these risks and factors are not exclusive
Management cautions against putting undue reliance on forward-looking statements or projecting any future assumptions based on such statements Forward-looking statements speak only as of the date of this IRP public advisory group presentation and EPE does not undertake to update any forward-looking statement contained herein except to the extent the events or circumstances constitute material changes in this IRP that are required to be reported to the New Mexico Public Regulation Commission (NMPRC or Commission) pursuant to its IRP Rule 1773 New Mexico Administrative Code
Safe Harbor Statement
5 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Fire Escape Routes
bull Please sign in You will be added to our PAG distribution listndash Skype participants can email NMIRPepelectriccom
bull Facilities
bull Recording of Meetings
bull Terms Glossary
Safety and Basics
4 EPE Proprietary Material
Certain matters discussed in this Integrated Resource Plan (IRP) public advisory group presentation other than statements of historical information are forward-looking statements made pursuant to the safe harbor provisions of the Section 27A of the Securities Act of 1933 as amended and Section 21E of the Securities Exchange Act of 1934 as amended Such statements are subject to a variety of risks uncertainties and other factors most of which are beyond El Paso Electric Companys (EPE or the Company) control and many of which could have a significant impact on the Companys operations results of operations and financial condition and could cause actual results to differ materially from those anticipated Additional information concerning factors that could cause actual results to differ materially from those expressed in forward-looking statements is contained in EPEs most recently filed periodic reports Any such forward-looking statement is qualified by reference to these risks and factors EPE cautions that these risks and factors are not exclusive
Management cautions against putting undue reliance on forward-looking statements or projecting any future assumptions based on such statements Forward-looking statements speak only as of the date of this IRP public advisory group presentation and EPE does not undertake to update any forward-looking statement contained herein except to the extent the events or circumstances constitute material changes in this IRP that are required to be reported to the New Mexico Public Regulation Commission (NMPRC or Commission) pursuant to its IRP Rule 1773 New Mexico Administrative Code
Safe Harbor Statement
5 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Certain matters discussed in this Integrated Resource Plan (IRP) public advisory group presentation other than statements of historical information are forward-looking statements made pursuant to the safe harbor provisions of the Section 27A of the Securities Act of 1933 as amended and Section 21E of the Securities Exchange Act of 1934 as amended Such statements are subject to a variety of risks uncertainties and other factors most of which are beyond El Paso Electric Companys (EPE or the Company) control and many of which could have a significant impact on the Companys operations results of operations and financial condition and could cause actual results to differ materially from those anticipated Additional information concerning factors that could cause actual results to differ materially from those expressed in forward-looking statements is contained in EPEs most recently filed periodic reports Any such forward-looking statement is qualified by reference to these risks and factors EPE cautions that these risks and factors are not exclusive
Management cautions against putting undue reliance on forward-looking statements or projecting any future assumptions based on such statements Forward-looking statements speak only as of the date of this IRP public advisory group presentation and EPE does not undertake to update any forward-looking statement contained herein except to the extent the events or circumstances constitute material changes in this IRP that are required to be reported to the New Mexico Public Regulation Commission (NMPRC or Commission) pursuant to its IRP Rule 1773 New Mexico Administrative Code
Safe Harbor Statement
5 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Meetings will follow the agenda bull Questions
ndash Public advisory group may ask clarifying questions during presentationndash Questions that require a longer explanation will be answered at the end of
the presentationndash Skype attendees may type in a question in instant message box
bull Discussion will followndash Facilitator will assist during discussionndash All public input and requests submitted in writing will be responded to in
writingbull Keep communications respectful and to the point
Ground RulesMeeting Rules and Guidelines
Joint Stipulation Case No 15-00241-UT6 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Updated Schedule ndash Public Advisory Group Meetings
Moved DG presentation to 8317
7 EPE Proprietary Material
See full size schedule at end of packet
Moved Renewable Portfolio Standard Impacts to 972017
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Integrated Resource PlanPublic Advisory Process
8 EPE Proprietary Material
bull The purpose of the public advisory process is to receive public input and solicit public commentary concerning resource planning and related resource acquisition issues
bull - NM Rule 17739 (H)
bull Meeting Schedules and Agendasndash Participants may add their own presentations to the
agendas for the January and February meetings
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Integrated Resource Plan
Operational ConsiderationsRequirements for Future Resourcesand Assessment of need for Additional Resources
Omar GallegosDirector of Resource Planning and Management
9 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull System operational behaviorbull Import limitationsbull Contingency reserves and reserve marginbull Variability of intermittent renewable resourcesbull Generation dispatch and baseload generationbull Age of retirement resources
Resource Planning Considerations forOperational Reliability
10 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
11 EPE Proprietary Material
bull Bulk Electric System flows across tie-lines dictated by load draw and physics
bull As load varies imports change almost immediately and then local generation adjusts to reset balance
bull Need to maintain imports within transmission limitations
bull Example of transmission line overloading resulting in a blackout
Operational ReliabilitySystem Operational Dynamic Behavior
EP
E L
oad
Loca
l Gen
Impo
rts Res
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
12 EPE Proprietary Material
bull System model for Capacity Expansion analysis
bull Limitations on purchased power and sales
Operational ReliabilityModelling of Transmission Import Limitations
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
13 EPE Proprietary Material
bull Cover unexpected loss of generator resource
bull Cover unexpected loss of transmission line (n-1)
bull Cover load growth over forecast
Operational ReliabilityImportance of Reserve Requirements
EP
E L
oad
Loca
l Gen
Impo
rts Res
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
14 EPE Proprietary Material
bull Need to consider how to mitigate if penetration of renewables increasesbull There are options need to be conscious of intermittency
Operational ReliabilityImpacts of Intermittent Generation Resources
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
15 EPE Proprietary Material
Operational ReliabilityDispatch Characteristics and Dispatch Order
bull Dispatch order
bull Resource dispatch ability
bull Resource ability for daily cycling
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Safety Personnel safety working in proximity to high pressure systems
bull Reliability Availability and risk of catastrophic failure
bull Cost Effectiveness Unit characteristics and resulting operating cost Including consideration for any investment required for life extensions
Generation Unit AgeOperational Reliability
EPE Proprietary Material16
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Questions
17 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Integrated Resource PlanSystem Operations ndash Reliability Import Limits
and Balancing
Dave HawkinsVice President - System Operations Resource
Planning amp Management
18 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull I most cost effective resource portfolio means those supply-side resources and demand-side resources that minimize the net present value of revenue requirements proposed by the utility to meet electric system demand during the planning period consistent with reliability and risk considerations
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17737 - Definitions
19 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull (6) amount of capacity obtained or to be obtained through existing purchased power contracts or agreements relied upon by the utility including the fuel type if known and contract duration
bull (8) amount of capacity and if applicable energy provided annually to the utility pursuant to wheeling agreements and the duration of such wheeling agreements
bull (10) reserve margin and reserve reliability requirements (eg FERC power pool etc) with which the utility must comply and the methodology used to calculate its reserve margin
20 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull (1) To identify the most cost-effective resource portfolio utilities shall evaluate all feasible supply and demand-side resource options on a consistent and comparable basis and take into consideration risk and uncertainty (including but not limited to financial competitive reliability operational fuel supply price volatility and anticipated environmental regulation) The utility shall evaluate the cost of each resource through its projected life with a life-cycle or similar analysis The utility shall also consider and describe ways to mitigate ratepayer risk
bull (2) Each electric utility shall provide a summary of how the following factors were considered in or affected the development of resource portfoliosndash (d) fuel diversityndash (e) susceptibility to fuel interdependenciesndash (g) system reliability and planning reserve margin requirements
17739(G) ndash Integrated Resource Plans for Electric Utilities
21 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
22 EPE Proprietary Material
System Operations Resource Planning amp Management
Sales ------Interchange----- Purchases
Load + Losses Power Generated
Demand SupplyFrequency
Decrease Increase
60- +
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Federal Energy Regulation Commission (FERC)bull North American Electric Reliability Corporation
(NERC)
Regulatory Authorities
23 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Reliability Of The Bulk Power System
24 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Western Interconnection Balancing Authorities
25 EPE Proprietary Material
Boundaries are approximate and for illustrative purposes only
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
26 EPE Proprietary Material
bull Regulating Reserves (Real Time Power Balancing)ndash BAL-001
bull ldquoTo control Interconnection frequency within defined limitsrdquondash BAL-005-02b
bull ldquoensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achievedrdquo
ndash BAL-006-2bull ldquohellipprocess for monitoring Balancing Authorities to ensure that
over the long term Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligationsrdquo
Operating Reserves ndash Generation Needed Above Current LoadNERC Reliability Standards
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
27 EPE Proprietary Material
bull Contingency Reserves (Replacement Power due to Loss of Generation)ndash BAL-002
bull ldquohellipto ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within the defined limits following a Reportable Disturbancerdquo
ndash BAL-002-WECCbull ldquoTo specify the quantity and types of Contingency Reserve required to
ensure reliability under normal and abnormal conditionsrdquobull Frequency Response (Replacement Power due to Grid
Disturbance)ndash BAL-003
bull ldquoTo require sufficient Frequency Response from the Balancing Authority to maintain Interconnection Frequency within predefined bounds by arresting frequency deviations and supporting frequency until the frequency is restoredhelliprdquo
NERC Reliability Standards Continued
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
28 EPE Proprietary Material
bull Real Time Assessment of System Conditionsndash TOP-001-3
bull ldquoTo prevent instability uncontrolled separation or Cascading outages that adversely impact the reliability of the Interconnection by ensuring prompt action to prevent or mitigate such occurrencesrdquo R13 Each Transmission Operator shall ensure that a Real-time
Assessment is performed at least once every 30 minutes R14 Each Transmission Operator shall initiate its Operating
Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment
R15 Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded
NERC Reliability Standards Continued
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Load Duration Curve with Operating Reserves
29 EPE Proprietary Material
0100200300400500600700800900
1000110012001300140015001600170018001900200021002200
0 3 6 8 11
14
17
20
22
25
28
31
33
36
39
42
45
47
50
53
56
59
61
64
67
70
73
75
78
81
84
86
89
92
95
98
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
bull Ability to meet operating reserve determined by the generators ramp ratendash ldquoThe rate expressed in megawatts per minute that a generator changes
its outputrdquobull Aggregate of individual generators ramp rates provide operating reserve
capability Examplendash Newman Unit 1 3 MWminndash Rio Grande Unit 8 5 MWminndash Total 8 MWmin
bull EPErsquos Montana Units and Rio Grande Unit 9 contribute to reserves even when not synchronized to the electric grid (50 MWmin ramp rates)
Meeting Operating Reserves - EPErsquos Local Generation
80 MW Contingency Reserves in 10 minutes
30 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Regulating Reserves System Load vs Solar
31 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Regulating Reserves System Load vs Solar
32 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Regulating Reserves System Load vs Solar
33 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Contingency Reserves - Southwest Reserve Sharing Group
34 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
Frequency Response - 2011 San Diego Blackout
35 EPE Proprietary Material
36 EPE Proprietary Material
EPE amp Southern New Mexico Import Capabilities
- 100
TEP
EPE1492 MW local
gen (Net)
PNM
SPP
37 EPE Proprietary Material
Questions
38 EPE Proprietary Material
Integrated Resource PlanExisting Conventional Resources and System Generation
Retirement Plan and Process
Andy RamirezVice President - Power Generation
39 EPE Proprietary Material
bull C Description of existing resources The utilityrsquos description of its existing resources used to serve its jurisdictional retail load at the time the IRP is filed shall includendash (1) name(s) and location(s) of utility-owned generation
facilitiesndash (2) rated capacity of utility-owned generation facilitiesndash (5) existing generation facilitiesrsquo expected retirement datesndash (7) estimated in-service dates for utility-owned generation
facilities for which a certificate of public convenience and necessity (CCN) has been granted but which are not in-service
40 EPE Proprietary Material
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17739(C) ndash Integrated Resource Plans for Electric Utilities
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE amp Southern New Mexico Import Capabilities
- 100
TEP
EPE1492 MW local
gen (Net)
PNM
SPP
37 EPE Proprietary Material
Questions
38 EPE Proprietary Material
Integrated Resource PlanExisting Conventional Resources and System Generation
Retirement Plan and Process
Andy RamirezVice President - Power Generation
39 EPE Proprietary Material
bull C Description of existing resources The utilityrsquos description of its existing resources used to serve its jurisdictional retail load at the time the IRP is filed shall includendash (1) name(s) and location(s) of utility-owned generation
facilitiesndash (2) rated capacity of utility-owned generation facilitiesndash (5) existing generation facilitiesrsquo expected retirement datesndash (7) estimated in-service dates for utility-owned generation
facilities for which a certificate of public convenience and necessity (CCN) has been granted but which are not in-service
40 EPE Proprietary Material
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17739(C) ndash Integrated Resource Plans for Electric Utilities
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Questions
38 EPE Proprietary Material
Integrated Resource PlanExisting Conventional Resources and System Generation
Retirement Plan and Process
Andy RamirezVice President - Power Generation
39 EPE Proprietary Material
bull C Description of existing resources The utilityrsquos description of its existing resources used to serve its jurisdictional retail load at the time the IRP is filed shall includendash (1) name(s) and location(s) of utility-owned generation
facilitiesndash (2) rated capacity of utility-owned generation facilitiesndash (5) existing generation facilitiesrsquo expected retirement datesndash (7) estimated in-service dates for utility-owned generation
facilities for which a certificate of public convenience and necessity (CCN) has been granted but which are not in-service
40 EPE Proprietary Material
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17739(C) ndash Integrated Resource Plans for Electric Utilities
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Integrated Resource PlanExisting Conventional Resources and System Generation
Retirement Plan and Process
Andy RamirezVice President - Power Generation
39 EPE Proprietary Material
bull C Description of existing resources The utilityrsquos description of its existing resources used to serve its jurisdictional retail load at the time the IRP is filed shall includendash (1) name(s) and location(s) of utility-owned generation
facilitiesndash (2) rated capacity of utility-owned generation facilitiesndash (5) existing generation facilitiesrsquo expected retirement datesndash (7) estimated in-service dates for utility-owned generation
facilities for which a certificate of public convenience and necessity (CCN) has been granted but which are not in-service
40 EPE Proprietary Material
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17739(C) ndash Integrated Resource Plans for Electric Utilities
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull C Description of existing resources The utilityrsquos description of its existing resources used to serve its jurisdictional retail load at the time the IRP is filed shall includendash (1) name(s) and location(s) of utility-owned generation
facilitiesndash (2) rated capacity of utility-owned generation facilitiesndash (5) existing generation facilitiesrsquo expected retirement datesndash (7) estimated in-service dates for utility-owned generation
facilities for which a certificate of public convenience and necessity (CCN) has been granted but which are not in-service
40 EPE Proprietary Material
1773 NMAC ndash Integrated Resource Plans for Electric Utilities17739(C) ndash Integrated Resource Plans for Electric Utilities
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
ndash (12)(a) the utility shall provide the percentage of kilowatt-hours generated by each fuel used by the utility on its existing system for the latest year for which such information is available
ndash (13) a summary of back-up fuel capabilities and options
41 EPE Proprietary Material
17739(C) ndash Integrated Resource Plans for Electric Utilities
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE Local GenerationRio Grande Power Plantbull Unit 6 ndash Steam Turbine ndash 50 MW 1957bull Unit 7 ndash Steam Turbine ndash 50 MW 1958bull Unit 8 ndash Steam Turbine ndash 150 MW 1972bull Unit 9 LMS 100 ndash Gas Turbine ndash 88 MW 2013
Montana Power Plantbull Unit 1 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 2 LMS 100 ndash Gas Turbine ndash 89 MW 2015bull Unit 3 LMS 100 ndash Gas Turbine ndash 89 MW 2016bull Unit 4 LMS 100 ndash Gas Turbine ndash 89 MW 2016
Copper Power Plantbull Unit 1 ndash Gas Turbine ndash 64 MW 1980
42 EPE Proprietary Material
Newman Power Plantbull Unit 1 ndash Steam Turbine ndash 80 MW 1960 bull Unit 2 ndash Steam Turbine ndash 80 MW 1963bull Unit 3 ndash Steam Turbine ndash 100MW 1966bull Unit 4 2x1 CC configuration ndash 220MW
bull Unit 4 GT1 ndash Gas Turbine ndash 70 MW 1975 bull Unit 4 GT2 ndash Gas Turbine ndash 70 MW 1975bull Unit 4 STM ndash Steam Turbine ndash 80 MW 1975bull Unit 4 1x1 CC configuration ndash 110 MW
bull Unit 5 2x1 CC configuration ndash 282 MWbull Unit 5 GT3 ndash Gas Turbine ndash 70 MW 2009 bull Unit 5 GT4 ndash Gas Turbine ndash 70 MW 2009bull Unit 5 STM ndash Steam Turbine ndash 142 MW 2011bull Unit 5 1x1 CC configuration ndash 141 MW
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE GenerationRemote Generationbull Palo Verde AZ-Nuclear ndash 633 MW
Local Generationbull Newman TX-GasOil ndash 762 MWbull Copper TX-Gas ndash 64 MWbull Rio Grande NM-Gas ndash 338 MWbull Montana Power TX-GasOil ndash 356 MW
Total EPE ndash 2153 MW
43 EPE Proprietary Material
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE GenerationBaseload ndash Nuclear (633 MW)bull Generator online at full load 24x7bull Generators and reactors not designed for cycling onoffbull Generators and reactors not designed for ramping output updown
Baseload ndash Conventional Steamer (481 MW)bull Boiler produce high-pressure steam to turndrive turbine for generatorbull Operations result in mechanical stresses and strains due to pressures and temperaturebull Establish operating boundaries for minimum downtime and minimum runtime to mitigate mechanical
impact of stresses and potential fatigue due to cyclingbull Generators brought online for continuous run days (typically weeks at time)bull Lower ramp rates (lag time for boiler to change steam pressure to ramp)
44 EPE Proprietary Material
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE GenerationIntermediate ndash Combined Cycle (505 MW)bull Combustion Turbine (ldquoCTrdquo) and Steam Turbine (ldquoSTrdquo)bull CT ndash gas combustion drives turbinebull Exhaust heat from CT is utilized to create steam to turn Steam Turbine (supplemented by gas)bull Most efficient of gas-fired generationbull May be cycled more often newer designs maybe cycled daily (however it comes with impacts)bull Faster ramp rates than Boiler Steamers
Peaking ndash Combustion Turbine (506 MW)bull Gas combustion drives turbinebull No steam ndash makes for quicker start timesbull Fastest ramp rates in ldquogas-firedrdquo categorybull No high-pressure steam componentsbull Maybe cycled daily and even multiple times per day
45 EPE Proprietary Material
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE GenerationCurrent Plan for Upcoming Retirements
Unit Name Fuel Type Gen Type CategoryCommission
YearAge
Current Planned
Retirement
Age at Retirement
Rio Grande 7 Gas Conventional Steam Baseload 1958 59 2022 64Newman 1 Gas Conventional Steam Baseload 1960 57 2022 62Newman 2 Gas Conventional Steam Baseload 1963 54 2022 59Newman 3 Gas Conventional Steam Baseload 1966 51 2026 60Newman 4 Gas Combined Cycle Intermediate 1975 42 2026 51Copper Gas Combustion Turbine Peaking 1980 37 2030 50Rio Grande 8 Gas Conventional Steam Baseload 1972 45 2033 61
46 EPE Proprietary Material
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
47 EPE Proprietary Material
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
48 EPE Proprietary Material
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull How adding renewable affects existing systemndash Intermittent resources ndash new CC amp new CTrsquos
bull PeakingNonpeaking Unitsbull Baseload ndash then vs nowbull Idling generation unitsbull Fuel Costs
Conclusion
49 EPE Proprietary Material
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Questions
50 EPE Proprietary Material
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
51 EPE Proprietary Material
Integrated Resource PlanTransmission and Distribution Systems
Overview and Projects
Clay DoyleVice President ndash Transmission and Distribution
and System Planning
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Outline - Transmission and Distribution
52 EPE Proprietary Material
bull Overview ndash Transmission amp Distributiono The ldquoBig Picturerdquo
o Generation ndashgt Transmission ndashgt Distribution -gt Serviceo ldquoThe Gridrdquo and EPErsquos place in the Grid
bull The IRP Rule Requirements
bull System Planning ndash TampDo Planning studies and methodologies per NERC reliability standardso TampD System Expansion Plano Distribution System Expansion Plan
bull Metering amp Metering Systemso Automated Meter Reading (AMR) System ndash EPErsquos Systemo Advanced Metering Infrastructure (AMI) Advanced Metering Systems (AMS)o AMIAMS vs AMR functionality costbenefits
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
(11) existing transmission capabilities
(a) the utility shall report its existing and under-construction transmission facilities of 115 kV and above including associated switching stations and terminal facilities the utility shall specifically identify the location and extent of transfer capability limitations on its transmission network that may affect the future siting of supply-side resources
(b) the utility shall describe all transmission planning or coordination groups to which it is a party including state and regional transmission groups transmission companies and coordinating councils with which the utility may be associated
IRP Rule Requirements1773 NMAC17739
53 EPE Proprietary Material
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Confidential
Palo VerdePhoenix AZ
Clayrsquos CasitaMesilla NM
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
In 30 seconds or less1 We Generate
2 We Inflate
3 We Transport
4 We deflate
5 We distribute
6 We deflate again
7 We Hook you up
Overview ndash Transmission amp DistributionThe BIG PICTURE From the Generator to your home
TRANSMISSION SYSTEM DISTRIBUTION SYSTEM
Substation Substation
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Substation
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
TRANSMISSION NETWORK or
ldquoGRIDrdquo
Overview ndash TransmissionThe BIG PICTURE From the Generator to your home
NERC
FERC
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Reliability Of The Bulk Power System
59 EPE Proprietary Material
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull El Paso Electric (EPE) is a member of the Western Electricity Coordinating Council (WECC)
bull WECC Interconnections (Dynamic)ndash Public Service of New Mexico (PNM) ndash 345 kV amp 115 kVndash Tri-State Generation and Transmission - 115 kVndash Tucson Electric Power (TEP)- 345 kV
bull Southwest Power Pool (SPP) ndash (Non Dynamic) ndash Excel Energy (SPS) ndash 345 kV
Overview ndash TransmissionEPE ndash How Wersquore Connected
60 EPE Proprietary Material
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
61 EPE Proprietary Material
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
OverviewSW Area EHV Transmission
62 EPE Proprietary Material
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
OverviewEPE Service Territory (Control Area)
63 EPE Proprietary Material
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Substation 138
kVDistribution Line
Distribution Transformer
138 kV
Overview ndash DistributionEPE ndash From the Substation to your home
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
DISTRIBTUION is a RADIAL
SYSTEM
Transmission
Transmission
Transmission
Overview ndash DistributionEPE ndash From the Substation to your home
Transmission
PRCPUCT
NECstandards
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPErsquos Standard Distribution Voltagesbull 239kV (24kV)bull 138kV (14kV)bull 42kV (4kV)
Overview ndash DistributionEPE ndash From the Substation to your home
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System Planning (Transmission)FERC Requirements
67 EPE Proprietary Material
bull Order No 888 (1996) Requires open access to transmission facilities for third parties to address undue discrimination and to bring more efficient lower cost power to the Nations electricity consumers ndash OPEN ACCESS
bull Order No 890 (2007) Requires coordinated open and transparent transmission planning processes to address undue discrimination ndash COORIDNATED amp OPEN PLANNING
bull Order No 1000 (2011) Requires transmission planning at the regional level adhere to the precepts of Order 890 to consider and evaluate possible transmission alternatives by third parties and produce a regional transmission plan requires the cost of transmission solutions chosen to meet regional transmission needs to be allocated to beneficiaries ndash REGIONAL PLANNING WITH COSTBENEFIT ALLOCATION
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System Planning (Transmission)FERC Requirements
68 EPE Proprietary Material
Order No 890 (2007)
bull EPE modified its Open Access Transmission Tariff (OATT) in 2008 to reflect the principals in Order 890bull coordination openness transparency information exchange comparability
dispute resolution and economic planning
bull EPE holds bi-annual Stakeholder meetings tobull Discuss upcoming Plansbull Discuss results of Plansbull Obtain input from Stakeholders
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System Planning (Transmission)FERC Requirements
69 EPE Proprietary Material
Order No 1000 (2011)
bull Requires EPE to a participate in regional planning process and a regional Plan
bull Requires a methodology for cost allocation be developed for regional projects that request and meet the standards for cost allocation
bull EPE amended its OATT and filed it at FERC to incorporate FERC Order 1000 requirements
bull Since the original filing EPE has made additional compliance filings incorporating additional FERC Orders
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System Planning (Transmission)FERC Requirements
70 EPE Proprietary Material
Cost Allocation Principals (FERC Order 1000)bull Costs allocated ldquoroughly commensuraterdquo with estimated benefits
bull Those who do not benefit from the transmission project are not allocated any costs
bull Benefit‐to‐cost thresholds must not exclude projects with significant net benefits
bull Cost allocation methods and identification of beneficiaries must be transparent
bull Different allocation methods could apply to different types of transmission facilities
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System Planning (10yr System Expansion Plan ndash TampD)
System Expansion Plan - Drivers Bi-Annual with material changes annually Load Forecast Distribution Expansion Plan Loads amp Resources Report Operational constraints and contingencies FERCNERCWECC PampO requirements
Distribution Expansion Plan - Drivers Annual Customer load growthprojections System maintenance amp reliability MaintainImprove Operational
capabilities
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Interconnections Ownership and Limitations
72 EPE Proprietary Material
System Planning (Transmission)
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
EPE Service Territory (Control Area)
73 EPE Proprietary Material
System Planning (Transmission)
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
74
Transmission System Planning1 Power Flow Model
System is modeled to Substation level (not to Distribution level)Validation
Using known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System PlanningEMS Power Flow Modeling Validation Contingencies
75 EPE Proprietary Material
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
76
Transmission System Planning2 Power Flow Model Validation
ValidationUsing known EMS Data Voltages amp Currents Substation load Line loading Line status Generation - local Generation - Import Generator capacity
Does the model truly represent the physical system
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
77
Transmission System Planning3 Power System Analysis
Both ldquoReal Timerdquo with EMS Data or Planning Studies using worst case loading
PLANNING ANALYSIS(The Game of ldquoWhat ifrdquo)
Utilizing the WECC powerflow models for the Heavy Summer seasons (EPE worst case) for each year of the 10 Year Planning Horizon EPE modelsbull Newest Load Forecast from
EPE Load Forecast Department
bull Newest Loads amp Resources from EPE Resource Development Department
EPE produces a 10 Year Transmission Plan on an Annual Basisbull Plan calls for Facilities
required to maintain EPE system operation within WECCNERC Criteria
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
78
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will new generation andor new transmission impact the system
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
79
Transmission System Planning3a Power System Analysis ndash Interconnection Studies
How will it impact the system System Planners propose solutions for contingencies
bull New Generationbull New Transmission
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
80
Transmission System Planning4 Power System Analysis ndash Compliance to Standards
NERC Standards(Your system must be able to do this)
TPL-001 N-0 (All Facilities in Service) All voltages and conductor loadings must be within normal limitsTPL-002 N-1 (Loss of Facility Line) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of loadTPL-003 N-2 (Loss of Multiple Facilities) All voltages and conductor loadings must be within emergency limits and the system shall remain stable with no cascading or uncontrolled loss of load
System Contingency Analysis ndash What will happen in N-0 N-1 N-2
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
81
Transmission System Planning5 Power System Analysis ndash ResolutionRecommendations
Stress Testing the Existing System ndash How do you plan to fix it
System Planners propose solutions for contingencies
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
82
Transmission System Planning4 Project Review and Scoping
System Planning prepares the description and motivation of each Transmission level projecto EPE driven Compliance Reliability Load Growth projectso Power Generation interconnection driven projectso Externally driven projects (TX-DOT UP-Railroad etc)o Planned Maintenance projects
Stakeholders considers each projectPurpose Priority Time-line Feasibility Options amp Alternatives LandPermit Acquisition Resource Availability Material Acquisition System Access Availability Cost Estimates etc
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
83
Transmission System Planning5 Projects List Resource Allocation Budgeting Project Management
System Planning project list based on Stakeholder Scoping Meeting Resultso EPE driven Compliance Reliability Load Growth Maintenance projectso Power Generation interconnection driven projectso Externally driven (TX-DOT UP-Railroad etc)o Break-In projects (AMRAD-Eddy Line Arroyo PST)
Stakeholders considers each projectResource AllocationAssignment Budget Prep Project Plan etc
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System PlanningEPErsquos 10yr TampD System Expansion Plan
84 EPE Proprietary Material
bull Updated annually
bull Complies with requirements of and supports all FERC Orders
bull Defines near-term and future system changesbull Accommodate new generation interconnectionsbull Meet future load growthbull Meetmaintainimprove operational capabilities bull Meetmaintainimprove reliability requirements
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System PlanningEPErsquos 10yr TampD System Expansion Plan - Projects
85 EPE Proprietary Material
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
System PlanningEPErsquos 10yr System Expansion Plan ndash TampD
86 EPE Proprietary Material
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull Automated Meter Readingbull Advanced (Smart) Meters
ndash Advanced Meter Reading (AMR) ndash Advanced Metering Infrastructure (AMI)ndash Advanced Metering System (AMS)
Metering amp Metering Systems
87 EPE Proprietary Material
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Automated Meter Reading - AMRResidential
Itron ndash Automated Meter Reading system (AMR) AMR Deployment 95 complete Meters are one way radio frequency (RF) communication close proximity reading One reading kWh residential per month up to three register values with polyphase
(maximum)bull Cost
Meter cost $35meter approximately $70meter installedbull Benefits
Improved accuracy Improved read efficiency (personnel vehicles etc) Improved safety
Metering amp Metering SystemsMetering ndash EPErsquos AMR Metering System
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Public Utility Commission of Texas (PUCT)2007
AMIAMS Requirementso Automated or Remote Meter Readingo Two-Way Communicationso Remote Disconnection amp Connection for meterso Capability to Time-Stamp Meter Datao Real-Time Access to Customer Usage Datao Means for Providing Price Signals to Customerso Interval Data ndash 15 Minutes or Shortero On-Board Storage of Meter Datao Communication Capability Beyond Meter (load control)o Must Comply with Open Standards and ANSI C1222
Metering amp Metering SystemsAdvanced Metering Systems
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
MDMS (back office stuff) Requirementso Data Security
o Data Validation amp Storage
o Data Communication - CustomerWeb Access
o Pricing TranslationSignals
o Billing Interface
o Customer Service Interface
o Data Volume Capability
Metering amp Metering SystemsAdvanced Metering Systems
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
AMIAMS Costs Estimateso Metering (Itron) $165 - $197 per meter $20meter installedo Comm It Interface MDMS cost allocation per meter $ (hosted)o 390000 meterso Expected Cost Range Estimate
($197 + $20) meter x 390000 meters = $846 MM + plus hosting
AMIAMS Benefits (Cost Mitigation)o Service Order Reductions (Disconnects amp Reconnects)o Energy Diversion (Theft) Reductiono Outage Managemento Demand Controlo Other
Metering amp Metering SystemsAMIAMS ndash Development CostBenefit
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
92
Metering amp Metering SystemsFunctionality AMR vs AMIAMS
$846 MM plus hosting cost
X
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull Big Picture ndash Generation -gt Transmission -gt Distribution -gt Home
bull Transmission is Networked System defines the ldquoGRIDrdquobull Distribution is Radial System between Sub and your homebull System Planning (Transmission)
ndash Power Flow Modeling Validating What ifrsquos FERCNERC rules Contingency Analysis Issues amp resolution etc
ndash Project list and prioritiesbull Transmission Line Construction
ndash Right of Way acquisition timebull Metering amp Metering System
ndash AMR vs AMIAMS functionality amp costndash AMR meters are not AMIAMS meters
Conclusion
93 EPE Proprietary Material
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
94 EPE Proprietary Material
QUESTIONS
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Discussion
95 EPE Proprietary Material
Please return feedback form to Facilitator before you leave or email to NMIRPepelectriccom
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
bull EPErsquos IRP website httpswwwepelectriccomcommunity2017-18-public-advisory-group-meetings
bull E-mail NMIRPepelectriccom to be added to the Public Advisory Group e-mail distribution list You will receive updates on available presentation material and future meetings Questions can also be submitted to this e-mail
For More Information
96 EPE Proprietary Material
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Acronyms
97 EPE Proprietary Material
AC - Alternating Current MW - MegaWatts (1000 kW)ACE - Area Control Error NERC - North American Reliability CouncilAMI - Advanced Metering Infrastructure NMAC - New Mexico Administrative Code
AMR - Automated Meter Reading NMPRC - New Mexico Public Regulation CommissionCC - Combined Cycle OATT - Open Access Transmission Tariff
CCN - certificate of convenience and necessity PDES - Phelps Dodge Energy ServicesCT - Combustion Turbine PNM - Public Service Company of New MexicoDC - Direct Current ROW - Right of Way
EPE - El paso Electric Company or EPEC SNMIC - Southern New Mexico Import CapabilityEPIC - El Paso Import Capability SOL - System Operating LimitFERC - Federal Energy Regulation Commission SRP - Salt River Project
FM - Freeport McMoRan SPP - Southwest Power PoolGen - Generation ST - Steam TurbineIRP - Integrated Resource Plan TEP - Tucscon Electric Power CompanyKV - Kilovolt (1000 volts) WECC - Western Electricity Coordinating Council
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
98 EPE Proprietary Material
Automatic Generation Control - Equipment that automatically adjusts generation in a Balancing Authority Area from a central location to maintain the Balancing Authorityrsquos interchange schedule plus Frequency Bias AGC may also accommodate automatic inadvertent payback and time error correction
Area Control Error - The instantaneous difference between a Balancing Authorityrsquos net actual and scheduled interchange taking into account the effects of Frequency Bias correction for meter error and Automatic Time Error Correction (ATEC) if operating in the ATEC mode ATEC is only applicable to Balancing Authorities in the Western Interconnection
Balancing Authority - The responsible entity that integrates resource plans ahead of time maintains load-interchange-generation balance within a Balancing Authority Area and supports Interconnection frequency in real time
Balancing Area - The collection of generation transmission and loads within the metered boundaries of the Balancing Authority The Balancing Authority maintains load-resource balance within this area
Bulk Power System - (A) facilities and control systems necessary for operating an interconnected electric energy transmission network (or any portion thereof) and (B) electric energy from generation facilities needed to maintain transmission system reliability
NERC Glossary of Terms
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Cascading - The uncontrolled successive loss of System Elements triggered by an incident at any location Cascading results in widespread electric service interruption that cannot be restrained from sequentially spreading beyond an area predetermined by studies
Contingency Reserves - The provision of capacity deployed by the Balancing Authority to meet the Disturbance Control Standard (DCS) and other NERC and Regional Reliability Organization contingency requirements
Direct Control Load Management - Demand-Side Management that is under the direct control of the system operator DCLM may control the electric supply to individual appliances or equipment on customer premises DCLM as defined here does not include Interruptible Demand
Frequency Response - The ability of a system or elements of the system to react or respond to a change in system frequency
NERC Glossary of Terms
99 EPE Proprietary Material
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
100 EPE Proprietary Material
Interconnection - A geographic area in which the operation of Bulk Power System components is synchronized such that the failure of one or more of such components may adversely affect the ability of the operators of other components within the system to maintain Reliable Operation of the Facilities within their control
Net Actual Interchange - The algebraic sum of all metered interchange over all interconnections between two physically Adjacent Balancing Authority Areas
Net Scheduled Interchange - The algebraic sum of all Interchange Schedules across a given path or between Balancing Authorities for a given period or instant in time
Non-Spinning Reserve - 1 That generating reserve not connected to the system but capable of serving demand within a specified time2 Interruptible load that can be removed from the system in a specified time
Operating Reserve - That capability above firm system demand required to provide for regulation load forecasting error equipment forced and scheduled outages and local area protection It consists of spinning and non-spinning reserve
NERC Glossary of Terms
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-
Operating Reserve - Spinning The portion of Operating Reserve consisting of Generation synchronized to the system and fully available to serve load within the Disturbance Recovery Period following the contingency event or Load fully removable from the system within the Disturbance Recovery Period following the contingency event
Ramp Rate ndash The rate expressed in megawatts per minute that a generator changes its output
Regulating Reserve - An amount of reserve responsive to Automatic Generation Control which is sufficient to provide normal regulating margin
Reportable Disturbance - Any event that causes an ACE change greater than or equal to 80 of a Balancing Authorityrsquos or reserve sharing grouprsquos most severe contingency
System Operating Limit - The value (such as MW Mvar amperes frequency or volts) that satisfies the most limiting of the prescribed operating criteria for a specified system configuration to ensure operation within acceptable reliability criteria
NERC Glossary of Terms
101 EPE Proprietary Material
- Slide Number 1
- Meeting Agenda
- Welcome and Introduction
- Safety and Basics
- Safe Harbor Statement
- Ground Rules
- Updated Schedule ndash Public Advisory Group Meetings
- Integrated Resource Plan
- Slide Number 9
- Resource Planning Considerations forOperational Reliability
- Slide Number 11
- Slide Number 12
- Slide Number 13
- Slide Number 14
- Slide Number 15
- Operational Reliability
- Questions
- Slide Number 18
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 20
- Slide Number 21
- System Operations Resource Planning amp Management
- Regulatory Authorities
- Reliability Of The Bulk Power System
- Western Interconnection Balancing Authorities
- Slide Number 26
- Slide Number 27
- Slide Number 28
- Load Duration Curve with Operating Reserves
- Meeting Operating Reserves - EPErsquos Local Generation
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Regulating Reserves System Load vs Solar
- Contingency Reserves - Southwest Reserve Sharing Group
- Frequency Response - 2011 San Diego Blackout
- Slide Number 36
- EPE amp Southern New Mexico Import Capabilities
- Questions
- Slide Number 39
- 1773 NMAC ndash Integrated Resource Plans for Electric Utilities
- Slide Number 41
- EPE Local Generation
- EPE Generation
- EPE Generation
- EPE Generation
- EPE Generation
- Slide Number 47
- Slide Number 48
- Conclusion
- Questions
- Slide Number 51
- Outline - Transmission and Distribution
- IRP Rule Requirements1773 NMAC
- Slide Number 54
- Slide Number 55
- Slide Number 56
- Slide Number 57
- Slide Number 58
- Reliability Of The Bulk Power System
- Overview ndash Transmission
- Western Electricity Coordinating Council(the ldquoWestern Gridrdquo)
- Overview
- Overview
- Overview ndash Distribution
- Overview ndash Distribution
- Overview ndash Distribution
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (Transmission)
- System Planning (10yr System Expansion Plan ndash TampD)
- Slide Number 72
- Slide Number 73
- Slide Number 74
- System Planning
- Slide Number 76
- Slide Number 77
- Slide Number 78
- Slide Number 79
- Slide Number 80
- Slide Number 81
- Slide Number 82
- Slide Number 83
- System Planning
- System Planning
- System Planning
- Metering amp Metering Systems
- Slide Number 88
- Slide Number 89
- Slide Number 90
- Slide Number 91
- Slide Number 92
- Conclusion
- Slide Number 94
- Discussion
- For More Information
- Acronyms
- Slide Number 98
- NERC Glossary of Terms
- Slide Number 100
- NERC Glossary of Terms
-