pacificorp 2014 annual progress report - final · 2014 annual progress report 5 iv. pinto add 3rd...

TRANSMISSION PLANNING

Craig Quist

Director of Area/Transmission Planning East PacifiCorp

1407 West North Temple, Suite 275 Salt Lake City, Utah 84116

(801)220-4264 PH (801)220-2842 FAX

Date: March 14, 2014 To: Mr. Tracy Rolstad, Chairman WECC Technical Studies Subcommittee Avista Corporation Post Office Box 3727 1411 East Mission Spokane, WA99220-3727, Mr. Enoch Davies WECC Technical Staff 155 North 400 West, Suite 200 Salt Lake City, Utah 84103-1114 Subject: PacifiCorp 2014 Annual Progress Report Dear: Tracy and Enoch, In accordance with WECC Planning Coordinating reporting guidelines, please find attached PacifiCorp’s 2014 Annual Progress Report outlining significant additions and changes to our system. Should you have any questions, or need additional information, please contact me at (801) 220-4264. Sincerely,

Craig Quist

Craig Quist TSS Member, PacifiCorp cc: TSS Members WECC Staff Rick Vail JD Podlesnik

Table of Contents

A. Planned Transmission and Generation Projects 1

I. Carbon Plant Decommissioning/Replacement (2015) ...................................................2

II. Huntington- Mona 345 kV Line, Series Reactor at Mona/Clover (2014) ...................3

III. Lakeside II Transmission Network Upgrades (2014) ...................................................4

IV. Pinto Add 3rd Phase Shifting Transformer (2015) .......................................................5

V. TOT4A Voltage Support Project (June 2008 to December 2014) ................................6

VI. Standpipe - Construct New 230kV Substation (2016) ...................................................7

VII. Wallula to McNary 230 kV #2 Transmission Line (December 2017) ..........................9

VIII. Gateway West Transmission Project ............................................................................10

IX. Gateway South Transmission Project ..........................................................................16

X. Gateway Central Transmission Project .......................................................................20

XI. Future Generation Projects ...........................................................................................22

B. Waiver of “Significant Transmission Project Status” 23

Table 7: Planned Transmission Projects (Waiver) ......................................................................23

Table 8a: Planned Generation Interconnection Projects (PACE) – Waiver ...............................30

Table 8b: Planned Generation Interconnection Projects (PACW)- Waiver ................................32

C. Updates to the Annual Progress Report from the Previous Submittal (2013) 33

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2014 Annual Progress Report

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PacifiCorp 2014 Annual Progress Report to WECC

This annual progress report submission is divided into three separate sections, including a summary of all BES transmission projects1 and generation in Section A; a request for Waiver of “Significant Project Status” in Section B; and updates to the annual progress report from the previous submittal (2013) in Section C2.

A. Planned Transmission and Generation Projects This annual progress report is intended to 1) capture all BES transmission and generation projects that may have a significant impact on the reliability of the Western Interconnection; and 2) to inform neighboring systems in a timely manner regarding new facility additions to your system and associated system operation. Technical studies have demonstrated that all existing facilities and planned facility additions, as well as associated operating procedures, are in conformance with NERC Planning Standards and WECC System Performance Regional Business Practice. The following projects are included in this Annual Progress Report:

All major new and upgraded BES transmission facilities. Such projects include, but are not limited to, new transmission facilities, transmission redesigns or upgrades, permanent removal of existing transmission facilities, or other changes (e.g., operating procedures) that may significantly alter the operation of the transmission facilities

Any facilities not covered under the BES transmission definition that may have a significant impact on the reliability of the Western Interconnection

All generation projects (200 MW or greater) connected to the transmission system through step-up transformers. Such projects include, but are not limited to, new generation plants, generation repower or upgrades that may significantly alter the operation of the generation facilities

1 BES projects will be determined based on the definition that was effective as of July 1, 2013. 2 This last section is intended to be a guide for comparing back-to-back Annual Progress Report submissions.

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I. Carbon Plant Decommissioning/Replacement (2015)

A. Project Description Name: Carbon Plant Decommissioning Participants: PacifiCorp One-Line Diagrams: N/A Status: The projected decommissioning date is April 15, 2015 Generation: Carbon Plant Facilities: The Carbon Plant decommissioning will require the addition of the following facilities: -15/+85 MVAr 138 kV static VAr system (SVS), two 138 kV 15 MVAr capacitor banks with associated breakers at the Mathington substation. The addition of a 138 kV phase shifting transformer (PST) at the Upalco substation and the relocation of the Spanish Fork 138 kV series line reactors to the Upalco substation. B. Studies: Studies are Ongoing. C. Impact on Other Systems The Carbon decommissioning has been prompted by EPA regulation changes, and as such the removal of a coal-fired power plant is projected to benefit the environment as a whole. The combined decommissioning and area reinforcement projects will not degrade the central Utah transmission system.

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II. Huntington- Mona 345 kV Line, Series Reactor at Mona/Clover (2014)

A. Project Description Name: Huntington – Mona 345 kV Line, Series Reactor at Mona/Clover Participants: PacifiCorp One-Line Diagram: N/A Status: The projected in-service date for this project is 2014 Generation: N/A Facilities: Install an 18 ohm series reactor in the Mona- Huntington 345 kV line at Mona to increase transfer capability across the “North of Sigurd/Huntington” transmission path. B. Studies A study was conducted to determine the optimum reactor size. It was determined that an 18 ohm series reactor provided the most optionality in future resource location (Huntington vs. Sigurd), while increasing the North of Huntington/Sigurd flow limits. C. Impact on Other Systems This project will support an increase in south to north transfers from southern to northern Utah.

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III. Lakeside II Transmission Network Upgrades (2014)

A. Project Description Name: Lakeside II Transmission Network Upgrades Participants: PacifiCorp One-Line Diagram: N/A Status: The projected in-service date is June 1, 2014 Generation: Lakeside II generating facility Facilities: Transmission of energy from the generation facility to beyond Steel Mill substation requires the installation of two new 345 kV breakers and looping in of the Camp Williams – Emery 345 kV line at Spanish Fork substation. Also required is a reconductoring of the 10 mile Spanish Fork – Tanner 138 kV line and communication fiber to Hale substation. B. Studies Technical studies have been performed to evaluate adding the Lake Side II Generation. Defined system improvements were identified as part of the studies. C. Impact on Other Systems Transmission improvement should have minimal inputs on the Western Interconnection.

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IV. Pinto Add 3rd Phase Shifting Transformer (2015)

A. Project Description

Name: Pinto Add 3rd Phase Shifting Transformer Addition Participants: PacifiCorp One-Line Diagram: N/A

Status: The projected in-service date for this project is December 31, 2015

Generation: N/A

Facilities: Install the third 345 kV /400 MVA, phase shifting transformer in parallel with the two existing phase shifting transformers in a new bay at the Pinto substation. Improvements include a new transformer pad, extension of bus work, a new 345kV breaker, protection and control equipment and other new equipment.

B. Studies Studies have shown that the Pinto phase shifters are the limiting element for the TOT2B1 transmission path rating. Phase shifting capacity must be increased in order to meet network obligations. C. Impact on Other Systems

Addition of a third phase shifting transformer at Pinto will ultimately result in an increase in the TOT2B1 transmission path rating, which has an interaction with other TOT2 paths (TOT2A, TOT2C and Path 27-IPP DC Line). Ultimately, WECC path rating studies will be performed to fully define this interaction.

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V. TOT4A Voltage Support Project (June 2008 to December 2014)

A. Project Description Name: TOT4A Voltage Support Project Participants: PacifiCorp (Sponsor) One-Line Diagram: N/A Status: Technical studies have been completed and voltage support facilities have been included in the PacifiCorp capital budget. The projected in-service date for each facility is noted below. Generation: N/A Facilities: The following facilities have been identified for Wyoming voltage support:

Atlantic City 230 kV, 15 MVAr Capacitor (In-service: October 2010)

Riverton 230 kV, 30 MVAr Capacitor (In-service: August 2010)

Midwest 230 kV, 30 MVAr Capacitor (In-service: October 2010)

Dynamic voltage control in the Miners Area has been superseded by Standpipe 230 KV Synchronous Condenser project-Projected in-service date for (2016)

B. Studies Wyoming 2010 transfer capability studies, which evaluated the impacts of projected Wyoming load growth (both projected and large customer) on the TOT4A path rating, have identified the need for additional voltage support facilities (see facilities above). Studies have been shared with other Wyoming transmission owners. C. Impact on Other Systems

Technical studies have indicated that based on projected load growth, the reactive support is needed to maintain the TOT4A/4B Nomogram at its current transfer levels. As these facilities are required for south central Wyoming voltage support, no other paths are affected.

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VI. Standpipe - Construct New 230kV Substation (2016) A. Project Description Name: Standpipe- Construct New 230kV Substation Participants: PacifiCorp One-Line Diagram: N/A Status: The projected in-service date for this project is 06/30/2016 Generation: Synchronous Condenser (+60/-35 MVAr)

Facilities: Construct a new 230 kV substation called Standpipe. The new substation will be located near Miners substation, and will intercept the existing Platte-Miners-Standpipe 230 kV line, resulting in the Platte-Standpipe-Freezeout 230kV line. Miners will be fed radially from Standpipe following completion of the project. A new or relocated synchronous condenser with a minimum capability of +60/-35 MVAr will be installed at Standpipe to provide dynamic reactive support in the region. Additional project scope to improve voltage stability and reliability for customers on the south central Wyoming 230 kV transmission system includes the relocation of an existing 31.7 MVAr shunt reactor from Platte to Standpipe substation, installation of a 25 MVAr capacitor bank at Latham substation, implementation of coordinated shunt reactive device controls at Latham, Platte, Standpipe, Miners, and Foote Creek. The project will install a special protection scheme to trip local area wind generation for contingency conditions that result in low voltage in the Spence area of the Wyoming 230 kV system. Other system improvements to be completed under the project include reconfiguration of the Platte Substation 230 kV bus, relocation of the Standpipe line termination at Platte, installation of a new 230 kV circuit breaker at Platte, reconfiguration of the Latham 230 kV bus to accommodate the new shunt capacitor, and communications upgrades to facilitate relay upgrades and the special protection scheme.

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B. Studies The 2012 TOT4A Path Rating Study included sensitivity with the Standpipe reactive device. The results were shared with other utilities. C. Impact on Other Systems

As these facilities are required for south central Wyoming voltage support to maintain TOT4A transfers, only the TOT4B path is affected.

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VII. Wallula to McNary 230 kV #2 Transmission Line (December 2017)

A. Project Description Name: Wallula to McNary 230 kV #2 Transmission Line Participants: PacifiCorp (Sponsor) One-Line Diagram: N/A Status: This project is in Phase 2 of the WECC Three Phase Rating Process. The project has a planned in service date of December 2017. Generation: N/A Facilities: The Wallula to McNary 230 kV #2 line would be a single circuit transmission line with line terminals at Wallula and McNary substations. B. Studies Phase 2 studies are being performed; when complete they will be reviewed by the project review group. C. Impact on Other Systems This project has impacts to other regional facilities most notably BPA as the project has a terminal at BPA’s McNary Substation. Phase 2 studies are being performed and when complete will be reviewed by the project review group.

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VIII. Gateway West Transmission Project

Idaho Power and PacifiCorp (Rocky Mountain Power) jointly announced the Gateway West project in May 2007, to build and operate approximately 900 miles of new high-voltage transmission lines between the Windstar substation near Glenrock, Wyoming and the Hemingway substation near Melba, Idaho.

After completing Regional Planning and initial path rating studies, on February 6, 2009, Idaho Power was granted Phase 2 path rating status for the Gateway West Transmission Project, which included Stage 1 facilities needed to meet Idaho Power’s and PacifiCorp’s long-term regulatory requirement to serve loads, and Stage 2 facilities which were intended to provide extra transmission system capacity if commercially supported by other third parties requestors.

The Gateway West – Stage 1 project will include approximately 150 miles of 230 kilovolt (kV) lines in Wyoming and approximately 800 miles of 500 kV lines in Wyoming and Idaho. Gateway West– Stage 2 transmission facilities primarily consist of a second set of 500 kV circuits from southern Wyoming to western Idaho.

At the March 30, 2010, Gateway West and Gateway South combined project review meeting participants approved the Gateway Phase 2 Study Plan and agreed that Gateway transmission segments could be grouped into two logical project stages [1 and 2], which would be evaluated separately by WECC Phase 2 study group (or sub groups). Additionally, it was agreed that incremental transmission limitations for transmission segments that are added between stages, will be addressed via SOL (System Operating Limit) studies. [This same process was previously followed and successfully demonstrated by BPA and Avista for the West of Hatwai Expansion project.]

PacifiCorp reported in the 2011 Annual Progress Report submission that the third party requests and financial commitments that are necessary to support the Energy Gateway – Stage 2 facilities have not materialized. Therefore, PacifiCorp indicated that it would continue to pursue WECC path ratings for Stage 1 of Energy Gateway only at that time, and will not further pursue ratings for Stage 2 facilities. This Energy Gateway Project status update was also reported to TSS at the April 20-22, 2011, meeting in Westminster, Co.

For Gateway West – Stage 1 transmission paths located west of Populus [specifically Borah West and Midpoint West], Idaho Power was the project sponsor for each of the path ratings studied; additionally for Gateway West transmission paths located east of Populus [specifically TOT 4A, Aeolus West, Path C and Bridger/Anticline West], PacifiCorp was the project sponsor for the path ratings studied. At the completion of the Phase 2 path rating process, TOT 4A transmission path was granted Phase 3 status on December 13, 2010; Aeolus West, Bridger/Anticline West and Path C transmission paths were granted Phase 3 status on January 5, 2011; and Borah West and Midpoint West transmission paths were granted Phase 3 status on July 21, 2011.

The federal National Environmental Policy Act (NEPA) permitting process began in April 2007 when the companies filed the application with the BLM. Public Scoping meetings followed in

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June 2008. The BLM published its draft EIS July 29, 2011, and a year later in August 2012, identified the agency-preferred alternative routes for Gateway West.

In following the NEPA process, the Bureau of Land Management (BLM) has completed the Environmental Impact Statement (EIS) for the Gateway West project. The BLM released its final EIS on April 26, 2013, followed by the Record of Decision on November 14, 2013, providing a right-of-way grant for most of the project. The agency chose to defer its decision on the western-most portion of the project located in Idaho in order to perform additional review of the Morley Nelson Snake River Birds of Prey Conservation Area.

Based on the agreement between PacifiCorp and Idaho Power, executed in early 2012, PacifiCorp will assume responsibility for sponsoring all Gateway West transmission facilities through the NEPA process and through the project construction agreement phase.

Gateway West – Stage 1 Plan of Service and Planned Operating Date

An overview of the Gateway West – Stage 1 transmission system modification and in-service dates are summarized in Table 1 below and illustrated in Figures 1 and 2.

Table 1: Gateway West – Stage 1 Facilities and In-Service Dates

Gateway West – Stage 1 Transmission Project Facilities Date

TOT 4A (Path 37)

Construction of one new 230 kV circuit from Windstar to Aeolus (76 miles) [PAC owned facility]

2021-2024

Rebuild the DJ-Difficulty-Shirley Basin-Aeolus 230 kV line from 1-1272 ACSR/phase to a higher rated conductor. [PAC owned facility]

2021-2024

Aeolus West

Addition of three – 500/230 kV (1650 MVA) autotransformers (9 x 1Φ) at Aeolus [PAC owned facility]

2021-2024

Aeolus 230 kV SVC (-150/+300 MVAr), one-150 MVAr (230 kV MSC), one- 50 MVAr (230 kV), three – 100 MVAr (230 kV), four -200 MVAr (500 kV) shunt capacitors. [PAC owned facility]

2021-2024

Construction of one new 500 kV circuit from Aeolus to Anticline with 50% of series compensation (154 miles) [PAC owned facility]

2021-2024

Addition of a generator tripping scheme at Aeolus and Windstar [PAC owned facility]

2021-2024

Bridger/Anticline West (Path 19)

Addition of one - 500/345 kV (1500 MVA) auto transformer (3 x 1Φ) at Anticline [PAC owned facility]

2021-2024

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Addition of two 345 kV (750 MVA) phase-shifting transformers at Anticline [PAC owned facility]

2021-2024

Construction of one new 500 kV circuit from Anticline to Populus with 50% of series compensation (203 miles) [PAC owned facility]

2021-2024

Addition of one - 500/345 kV ( 2000 MVA) autotransformer (3 x 1Φ) at Populus [PAC owned facility]

2021-2024

Borah [/Populus] West (Path 17)

Construction of one new 500 kV circuit from Populus to Borah (55 miles) and new 500 kV circuit between Borah and Midpoint (88 miles). These line sections will be built by conversion of the operating voltage of the existing Kinport/Borah to Midpoint 345 kV line section to 500 kV [IPC owned facility], and the addition of a new 500 kV circuit between Populus and Borah [PAC owned facility]. A 500/345 kV (1500 MVA) autotransformer (3 x 1Φ) will be installed at Borah.

2020-2024

Construction of one new 500 kV circuit from Populus to Cedar Hill with approximately 45% series compensation. (118 miles) [PAC owned facility]

2020-2024

Construction of one new 500 kV circuit from Cedar Hill to Hemingway with approximately 45% series compensation. (161 miles) [PAC/IPC jointly owned facility]

2020-2024

Construction of one new 500 kV circuit from Cedar Hill to Midpoint. This line will connect the Idaho southern route to Midpoint for improved reliability. (34 miles) [PAC/IPC jointly owned facility]

This facility has been advanced from Gateway West – Stage 2

2020-2024

Midpoint West

Midpoint – Hemingway Section

This section of the project will include two-500 kV circuits:

The first 500 kV circuit from Midpoint to Hemingway will be developed by interconnecting the existing Midpoint – Summer Lake 500 kV line into the Hemingway Station. [PAC owned facility]

Construction of the second 500 kV circuit from Midpoint to Hemingway with approximately 50% series compensation. (126 miles) ) [PAC/IPC jointly owned facility]

This facility has been advanced from Gateway West – Stage 2

In-Service: July 2010

2020-2024

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Gateway West Single-Line Diagrams

The following diagrams depict the project and adjacent transmission paths.

Figure 1: Gateway West – Stage 1 (West of Bridger/Anticline)

230 kV to Rock Springs

230 kV to Aeolus/Creston

Bridger

Anticline

Goshen

Gateway Central

Kinport

Borah

Cedar Hills

Midpoint

Hemingway

500 kV toAeolus

500 kV to Robison Summit(Northern SWIP)

500 kV to Garrison(MISTI)500 kV to

Boardman

500 kV toCaptain Jack

500 kV toSummer Lake

230 kV to Point of Rocks

230 kV to Mustang

Three MileKnoll

345 kV to Ben Lomond

345 kV to Terminal

Populus

345 kV

345 kV

500 kV

500 kV

2- 1500 MVA

1 - 1500 MVA

1- 2000 MVA

1 - 1500 MVA

230 kV

Gateway West(Hemingway - Bridger/Anticline)

2 - 750 MVA+20 PSTO

500 kV345 kV230 kV

ExistingMP-SL

88 miles3 - 1272Skylark

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Figure 2: Gateway West – Stage 1 (East of Bridger/Anticline)

Windstar

230 kV to Pumpkin Butte

230 kV to Rock Springs

230 kV to Point of Rocks

230 kV to Mustang

230 kV to Casper

230 kV to Yellow Cake

Dave Johnston

Heward

500 kV to Populus

345 kV to Three Mile Knoll

345 kV to Populus

Bridger Anticline

500 kV to Clover

Aeolus

345 kV

500 kV

3 - 1500 MVA

1- 1500 MVA

500 kV

230 kV

230 kV

230 kV

SVC

Gateway West(Bridger - Aeolus - Windstar)

2 - 750 MVA+20 PSTO

44 milesRebuilt

27 milesRebuilt

500 kV345 kV230 kV

Gateway South

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Transfer Capability

The transfer capabilities vary for different portions of the Gateway West project, and are detailed in Table 2:

Table 2: Gateway West – Stage 1 Transmission Segments and Transfer Levels

Path Existing Rating (MW)

New Rating (MW)

Simultaneous Interaction

TOT 4A (Path 37) 937 (North to South)

2175 (North to South)

No Interaction

Bridger/Anticline West (Path 19)

2400 (East to West)

4100 (East to West)

Aeolus South

Path C (Path 20)

Bonanza West (Path 33)

Monument-Naughton

Rock Springs/Firehole West

Path C (Path 20) 1600/1250 (North-South/ South-North)

2250 Bi-Directional

Montana-Idaho (Path 18)

Bridger West (Path 19)


Aeolus West 2670 (East to West)

Aeolus South

TOT 1A (Path 30)


Borah West (Path 17) 2557 (East-West) 4450 (East-West) No Interaction

Midpoint West 2487 (East-West) 4400 (East-West) No Interaction

For the Gateway West Transmission Project, all study results comply with NERC TPL-001-0 thru TPL-004-0 Standards as well as WECC TPL - (001 thru 004) – WECC-CRT- 2-System Performance Criterion. Additionally, PacifiCorp, Idaho Power and NV Energy planning criteria were applied. Technical studies demonstrated that the transmission path ratings noted in Table 2 are independent of other established path

ratings, with the exception of the simultaneous interactions noted.

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IX. Gateway South Transmission Project

As part of Energy Gateway Transmission Expansion, PacifiCorp (Rocky Mountain Power) is planning to build a new high-voltage transmission line, known as Gateway South, extending approximately 400 miles from the Aeolus substation in southeastern Wyoming into the new Clover substation near Mona, Utah and 160 miles from Sigurd to Red Butte.

After completing Regional Planning and initial path rating studies, on February 6, 2009, PacifiCorp was granted Phase 2 path rating status for the Gateway South Transmission Project, which included Stage 1 facilities needed to meet PacifiCorp’s long-term regulatory requirement to serve loads, and Stage 2 facilities which were intended to provide extra capacity if commercially supported by equity partners and other third parties.

The Gateway South – Stage 1 transmission facilities include a 500 kV transmission line from the proposed Aeolus substation in southeast Wyoming (constructed as part of the Gateway West Project) to the Clover substation in central Utah, and a second 345 kV transmission line from the Sigurd substation near Richfield, Utah to the Red Butte substation near Central, Utah in southwestern Utah. Gateway South – Stage 2 transmission facilities primarily consist of a second 500 kV circuit from Aeolus substation to Clover substation and a 500 kV segment from Clover substation to the Crystal substation in southern Nevada.

At the March 30, 2010, Gateway West and Gateway South combined project review meeting participants approved the Gateway Phase 2 Study Plan and greed that Gateway transmission segments could be grouped into two logical project stages [1 and 2], which would be evaluated separately by WECC Phase 2 study group (or sub groups). Additionally, it was agreed that incremental transmission limitations for transmission segments that are added between stages, will be addressed via SOL (System Operating Limit) studies.

PacifiCorp reported the 2011 Annual Progress Report submission that the third party financial commitments that are necessary to support the Energy Gateway – Stage 2 facilities have not materialized. Therefore, PacifiCorp indicated that it would continue to pursue WECC path ratings for Stage 1 of Energy Gateway only at that time, and will not further pursue ratings for Stage 2 facilities. This Energy Gateway Project status update was also reported to TSS at the April 20-22, 2011, meeting in Westminster, Co.

For the transmission paths associated with Gateway South – Stage 1, specifically Aeolus South and TOT 2B/2C, PacifiCorp was the project sponsor for each of the path ratings studied. At the completion of the Phase 2 path rating process, Aeolus South transmission path was granted Phase 3 status on December 16, 2010, while the TOT 2B/2C transmission paths was granted Phase 3 status on June 21, 2011.

The BLM announced the start of Public Scoping for the project on April 1, 2011. Public Scoping continued through June 30, 2011, with meetings held throughout the proposed route. During this time the BLM obtained comments from interested parties on the project. On July 24, 2013, the BLM announced its Preliminary Agency Preferred Route for the project. A draft EIS was published by the BLM on February 21, 2014.

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Plan of Service and Planned Operating Date

An overview of the Gateway South – Stage 1 transmission system modifications and in-service dates are summarized in Table 3 and are illustrated in Figure 3.

Table 3: Gateway South – Stage 1 Facilities and In-Service Dates

Gateway South - Stage 1 Transmission Project Facilities Dates

TOT 2B1 (Path 78)

Addition of 60% series compensation on the 345 kV line between Huntington and Pinto, at Pinto [PAC owned facility]

In-Service: March 2011

TOT 2C (Path 35)

Construction of Red Butte 345 kV SVC (-75/+350 MVAr) for southwest Utah voltage control [PAC owned facility]

In-Service: May 16, 2011

Addition of the Harry Allen 345/230 kV #3 (375 MVA) transformer [NVE owned facility]

In-Service: June 17, 2011

Upgrade the series compensation on the 345 kV line between Three Peaks and Sigurd, at Three Peaks, to 1800/2160 Amps (Normal/Emergency) [PAC owned facility]

In-Service: June 2013

Construction of one new 345 kV circuit from Sigurd to Red Butte with 46% series compensation. (170 miles) [PAC owned facility]

June 2015

Modification of the Huntington RAS scheme to address transmission outages south of Red Butte. [PAC owned facility]

June 2015

Aeolus South

Loop-in both 345 kV circuits between Mona and Sigurd into Clover and add one - 345/138 kV (450 MVA) autotransformer at Clover [PAC owned facility]

In-Service: December 2012

Construction of one new 500 kV circuit from Aeolus to Clover with 50% series compensation (400 miles) and add one - 500/345 kV (2000 MVA) autotransformer (3 x 1Φ) at Clover [PAC owned facility]

2020-2022

Loop-in the 345 kV circuit between Huntington and Mona into Clover. [PAC owned facility]

2020-2022

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Figure 3: Gateway South – Stage 1 Single-Line Diagram

The following diagrams depict the project and adjacent transmission paths.

230 kV toWindstar

500 kV to Anticline

345 kV to Oquirrh/Limber

345 kV to Camp Williams

#4 #2 #3#1

Aeolus

Middle 1

Middle 2

Sigurd

Red Butte

Harry Allen

Clover

Mona

#1

345 kV

500 kV

345 kV

345 kV

345 kV

500 kV

230 kV

230 kV

SVC

SVC

Gateway South Single-line

500 kV345 kV230 kV

Gateway Central

Gateway West

500 kV construction,Energized at 345 kV

345 kV to Huntington

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Transfer Capability

The transfer capabilities vary for different portions of the Gateway South project, and are detailed in Table 4.

Table 4: Gateway South – Stage 1 Transmission Segments and Transfer Levels

Project Section Path Existing Rating (MW)

New Rating (MW)

Simultaneous Interaction

Aeolus – Clover Aeolus South 1700 (North-South)

Aeolus West,

Bridger/Anticline West

IPPDC (S-N)

Red Butte- Harry Allen

TOT 2C (Path 35)

300/300 (North-South / South-North)

400/580 (North-South/South-North) in 2011; increased to 600/580 MW (North-South/South-North) in 2015

IPP DC line, net 345 kV imports and line flows

Potentially the SWIP project path ratings

Pinto – Four Corners

TOT 2B1(Path 78)

530/600 (North-South / South-North)

600/600 (North-South / South-North) in 2011

IPP DC line, net 345 kV imports and line flows

Potentially the SWIP project path ratings

For the Gateway South – Stage 1 Project, all study results comply with NERC TPL-001-0 thru TPL-004-0 Standards as well as WECC TPL - (001 thru 004) – WECC-CRT- 2-System Performance Criterion. Additionally, PacifiCorp, Idaho Power and NV Energy planning criteria were applied. Technical studies demonstrated that the transmission path ratings noted in Table 4 are independent of other established path ratings, with the exception of the simultaneous interactions noted.

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X. Gateway Central Transmission Project To meet the increasing demand of northern Utah, future Gateway Central transmission facilities are needed. These facilities would provide a link between Gateway West and Gateway South transmission facilities and would provide needed load service to the Wasatch Front. Populus to Terminal Extending from southeast Idaho into northern Utah, the Populus to Terminal transmission line adds a new double-circuit, 345-kilovolt transmission line stretching approximately 135 miles from the Populus Substation built near Downey, Idaho, to the Terminal substation near the Salt Lake City airport. The Populus to Terminal project was placed in service November 19, 2010. Mona (Clover) to Oquirrh PacifiCorp is committed to providing safe, reliable, cost-effective power and has proposed a project to establish a new high-voltage transmission line and two new substations in Utah. The line will originate at the Clover substation to be built near the existing Mona substation in Juab County, and run north to the proposed Limber substation to be built in Tooele County. The line will continue from Limber and connect to the Oquirrh Substation in West Jordan. This project will traverse the areas around the communities of Cedar Fort, Eureka, Grantsville, Mona, Salt Lake City, South Jordan, Stockton, Tooele and West Jordan. The in-service date for this line was May 17, 2013 as noted in Table 5. Depending on the load service request of the Tooele Valley, a new 345/138 kV substation will be installed at Limber. Oquirrh to Terminal The line will be located in an existing high-voltage transmission line corridor. It will run from the Oquirrh substation near 10200 South and 5600 West in West Jordan, north to the Terminal substation, located due south of the Salt Lake City international airport. This section of new transmission will link together other new transmission sections – Mona to Oquirrh and Populus to Terminal – to complete the Gateway Central portion of the Energy Gateway Transmission Expansion Project. The in-service date for this line is noted in Table 5.

Plan of Service and Planned Operating Dates

An overview of the Gateway Central transmission system modification is summarized below.

Table 5: Gateway Central Facilities and In-Service Dates

Gateway Central - Transmission Facilities Dates

Populus- Terminal double circuit 345 kV (135 miles) In-Service: November 19, 2010

Addition of the 500 kV single circuit between Clover (Mona) and In-Service:

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Limber, energized at 345 kV (65 miles) May 17, 2013

Addition of the 345 kV double circuit between Limber and Oquirrh (32 miles). The Limber – Oquirrh #1 circuit will be initially energized at 138 kV for service to the Tooele Valley.

In-Service: May 17, 2013

Addition of the 345 kV double circuit between Oquirrh and Terminal (14 miles)

May 2017

Transfer Capabilities

The transfer capabilities of Path C vary, depending on Gateway West project staging, as indicated in Table 2.

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XI. Future Generation Projects

This section includes all significant generation projects (200 MW or greater) connected to or removed from the transmission system through step-up transformers or generation project that may have a significant impact on the reliability of the Western Interconnection. All projects not included in this list are in table 8a and 8b.

Table 6: Significant Generation Additions- PacifiCorp East/ West

Project Queue Number/Name

Location

(County, State)

Participants One-Line Diagram

Status Generation Capacity

Type Transmission Facilities (kV)

Studies

Lakeside II Utah, UT PacifiCorp On File Under construction

2014

681 MW Thermal Upgrade

TBD complete

Carbon Carbon, UT PacifiCorp On File 2015 Retirement

-67 MW Coal 138/13.8 kV Complete

Carbon Carbon, UT PacifiCorp On File 2015 Retirement

-105 MW Coal 138/13.8 kV Complete

375 Carbon, WY PacifiCorp On file 2020 230 MW Wind 230 kV Underway

398-B Bonneville, ID PacifiCorp TBD Suspended 288 MW Wind 238/345 kV Suspended

B. Waiverof“SignificantTransmissionProjectStatus”

Table 7 and 8 (a and b) summarize planned transmission and generation projects, respectively, within the PacifiCorp system for which waivers of “Significant Transmission Project Status” for the purpose of Project Coordination Review Process are being requested. The purposes of these projects are for serving local load, to enhance or maintain local reliability, and/or to reduce local capacity requirements. These projects are not expected to have significant impacts on the operation of the Western Interconnection.

Table 7: Planned Transmission Projects (Waiver)

Project Name Project Description

In Service Date

Casper Substation-Install 230/115 MVA transformer

Participants: PacifiCorp

Status: The projected in-service date is 2015.

Facilities: Add a second 230-115 kV transformer at Casper substation, including expanding the 115kV bus, installing four new breakers and reconnecting the existing WAPA Casper 115kV transmission line into the new line position.

Studies: Studies are ongoing. Planning studies show that in the summer of 2015 for an N-1 event of the loss of the PACE Casper 230/115 kV transformer overloads WAPA’s Refinery Tap-DJ south tap 115kV line segment. Studies also show that in 2014 the N-1-1 or N-2 contingencies of a loss of the Casper 230-115kV transformer and the Casper –WAPA Casper 115kV line will result in voltage collapse.

Impact on other Systems/Transfer paths: While the project will have a positive impact on WAPA, facilities in central Wyoming, it will not affect the flow of energy on other utilities’ systems outside of Casper. No transfer paths will be impacted by this project.

2015

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Project Name Project Description In Service Date

Mid Valley Substation-Replace 345-138kV, 450 MVA with 700 MVA Transformers



Facilities: Replace two 345-138kV 450MVA transformers at Mid Valley substation with 700 MVA units.

Studies: Studies are ongoing

Impact on other Systems/Transfer paths: The project will not affect the flow of energy on other utilities’ systems and is not connected to other utilities’ systems. No transfer paths will be impacted by this project.

2020

St. George Substation- Install 345kV/138kV transformer & expand yard



Facilities: This project includes three related segments necessary to provide anticipated growing energy demands in Southwest Utah and to maintain the Company’s compliance with NERC and WECC reliability standards. The three segments are as follows:

Red Butte Substation – Re-terminate Harry Allen 345kV Line & Reactor, and Add a 345kV Breaker.

Construct a New 345kV Yard at St. George Substation; Install a 700 MVA 345/138 Transformer, Line Termination and Two Breakers (one each @ 345kV and 138kV).

2020

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Re-energize the Existing Red Butte – St. George Line at 345kV: Connect line terminations to Red Butte 345kV and St. George 345kV switchyards.

Studies: Studies are ongoing

Impact on other Systems/Transfer paths: The project will affect flow on UAMPS and Deseret facilities in southwest Utah. No transfer paths will be impacted

Snow Goose 500/230kV substation



Facilities: New 500/230kV substation tapping PacifiCorp’s Captain Jack to Klamath Co-Gen 500 kV line. The 230kV line construction will include looping the existing Klamath Falls to Malin 230kV line into the new substation. The project is only connected to PacifiCorp facilities and is intended to provide load service redundancy

Studies: Studies are ongoing. Preliminary studies show system impacts for loss of the existing Malin 500/230 kV transformer starting in the 2018 period. No flow control devices are required as a result of this project.

Impact on other Systems/Transfer paths: Preliminary studies have been shared with BPA. The project will not affect the flow of energy on other utilities’ systems and is not connected to other utilities’ systems. No transfer paths will be impacted by this project.

2016

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Syracuse –Install 345/138 kV #2 Transformer



Facilities: Install a 345-138 kV transformer (T#6) including (1) 345 kV circuit breaker and (1) 138 kV circuit breaker at Syracuse substation.

Studies: studies are ongoing

Impact on other Systems/Transfer paths: The project will not affect the flow of energy on other utilities’ systems and is not connected to other utilities’ systems. No transfer paths will be impacted by this project.

2021

Table Mountain 500/230kV substation



Facilities: New 500/230 kV Substation tapping PacifiCorp’s Meridian to Dixonville 500 kV Line, tapping the existing Meridian-Grants Pass 230 kV line and adding a new 230 kV transmission line from the new substation to the existing Grants Pass 230 kV Substation. The project is only connected to PacifiCorp facilities and is intended to provide load service redundancy.

Studies: Studies are ongoing. Preliminary studies show system deficiencies for loss of one of the existing 500/230 kV transformers at Meridian Substation. The preliminary studies also show system impacts for loss of the existing 230 kV line from Meridian to Grants Pass. No flow control devices are required as a result of this project.

Impact on other Systems/Transfer paths: Studies will be shared with BPA. The project will not affect

2019

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the flow of energy on other utilities’ systems. The project is not connected to other utilities’ systems. No transfer paths will be impacted by this project.

Troutdale Substation, Add 3- 230 kV circuit breakers



Facilities: This project will install 3-230 kV circuit breakers at Troutdale substation, two on the lines to PGE Gresham and Linneman Substations, and one between the two Troutdale substation busses.

Studies: The project has been jointly studied with Portland General Electric and is required to mitigate TPL-002 and TPL-003 problems identified by screening in the interconnected local system.

Impact on other Systems/Transfer paths: The project involves protection system changes and upgrades that will impact BPA & PGE facilities in the Troutdale area and is being coordinated with BPA & PGE accordingly. The project does not affect the ratings of any non-protection related system component. No transfer paths will be impacted by this project.

2016

Union Gap 230/115 kV Transformer Addition


Status: The projected in-service date for this project is 2016.

Facilities: This project will construct a third 250 MVA transformer at Union Gap.

Studies: Studies show that for loss of one of the two existing 230-115 kV 150 MVA transformers at

2016

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Union Gap, the remaining transformer will overload, resulting in a possible NERC TPL-002 violation. Additionally, without the 3rd transformer and proposed re-built buses, 115 kV & 230 kV circuit breaker failures and bus faults may cause NERC TPL-003 violations. No flow control devices are required as a result of this project.

Impact on other Systems/Transfer paths: There are no impacts on other systems and no transfer paths will be impacted by this project.

Vantage –Pomona Heights 230 kV line


Status: This project is in the process of obtaining the necessary permits for construction.

Facilities: This project will construct a new 230kV line between the Vantage and Pomona Heights 230kV buses in Washington State.

Studies: Joint studies performed by the Mid-Columbia Study Team indicated the need for this project. For the loss of the existing Pomona - Wanapum 230 kV transmission line, impacts are evident in the Yakima/Mid C area. This project mitigates these problems.

Impact on other Systems/Transfer paths: This project is needed as reinforcement to the area transmission system and relieves system problems to the MIDC transmission owners, most notably BPA.

December 2016

Whetstone 230/115kV Substation



2015

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Facilities: Construct a new 230 to 115 kV substation in the White City Oregon vicinity with a 250 MVA transformer. This substation will tap PacifiCorp’s existing 230 kV line between Meridian and Grants Pass Substations. The project is intended to provide load service redundancy.

Studies: Annual TPL studies indicate that this project will resolve TPL-002 and TPL-003 violations. No flow control devices are required as a result of this project.

Impact on other Systems/Transfer paths: There are no impacts on other systems, the project will not affect the flow of energy on other utilities’ systems and this project is not connected to other utilities’ systems. No other transfer paths will be impacted by this project.

Table 8a: Planned Generation Interconnection Projects (PACE) – Waiver


Location Participants One-Line Diagram



Studies

Planned Generation East

154 Bonneville, ID PacifiCorp On file 2012 19.8 MW Wind 69 Underway

267-A Sweetwater, WY

PacifiCorp On file 2019 22 MW Wind 230 Underway

267-B Sweetwater, WY

PacifiCorp On file n/a 22 MW Wind 230 Underway

267-C Sweetwater, WY


267-D Sweetwater, WY


290-A Sweetwater, WY

PacifiCorp On file n/a 100.8 MW Wind 230 Underway

290-B Sweetwater, WY


290-C Sweetwater, WY


313 Beaver, UT PacifiCorp On file 2013 65 MW Geothermal 138 Closeout

323-A Power, ID PacifiCorp On file 2011 21.6 Wind 230 Underway

323-B Power, ID PacifiCorp On file 2011 21.6 MW Wind 230 Underway

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Studies

335 Converse, WY PacifiCorp On file 2013 49.6 MW Wind 230 Underway

367 Iron, UT PacifiCorp On file n/a 172 MW Solar 345 Underway

384 San Juan, UT PacifiCorp On file n/a 60 MW Wind 345 Underway

415 Beaver, UT PacifiCorp On file n/a 11 MW Thermal 138 Closeout

420 San Juan, UT PacifiCorp On file n/a 140 MW Wind 138 Underway

432 Salt Lake, UT PacifiCorp On file n/a 6.3 MW Other 230 Underway

437 Franklin, ID PacifiCorp On file n/a 0.5 MW Hydro 69 Underway

442 Madison, ID PacifiCorp On file n/a 5.6 MW Natural Gas

230 Underway

450 Millard, ID PacifiCorp On file n/a 50 MW Solar 69 Underway



457 Beaver, UT PacifiCorp On file n/a 2.1 MW Solar 69 Underway

459 Beaver, UT PacifiCorp On file n/a 3 Mw Solar 69 Underway

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Table 8b: Planned Generation Interconnection Projects (PACW)- Waiver

Project Queue Number




Studies

Planned Generation West

230 Klamath, OR PacifiCorp On file 2014 14 MW Geothermal 69 underway

237-B Skamania, WA

PacifiCorp suspended suspended 25 MW Hydro 230 suspended

237-C Skamania, WA

PacifiCorp suspended suspended 25 MW Hydro 230 suspended

276 Umatilla, OR PacifiCorp On file 2015 98.9 MW Wind 230 underway

373 Klamath, OR PacifiCorp On file 2012 5 MW Solar 500 underway

389-B Lake, OR PacifiCorp On file n/a 5 MW Solar 69 suspended

393 Lake, OR PacifiCorp On file n/a 27 MW Geothermal 115 underway

422 Yakima, WA PacifiCorp On file n/a 5 MW Solar 69 underway

430 Klamath, OR PacifiCorp On file n/a 12 MW Geothermal 69 underway

431 Siskiyou, CA PacifiCorp On file n/a 12 MW Geothermal 69 underway

C. Updates to the Annual Progress Report from the Previous Submittal (2013)

The following updates to the PacifiCorp 2013 Annual Progress Report were made in developing this document:

1) Black Rock –removed from 2014 report, in-service 2013

2) Carbon Plant Decommissioning- changed title in 2014 report

3) Grants Pass- Project name changed to Table Mountain 500/230kV substation project and moved to waiver portion of the report (Section B).

4) Huntington- Mona/ 345 kV Line Series Reactor at Mona/Clover – changed in service year to 2014

5) Klamath Falls 500/230 kV Substation- Project name changed to Snow Goose. Project moved to waiver portion of the report (Section B).

6) Midpoint-Summer Lake 500 kV line- in service, removed from report

7) Pinto Phase Shifting Transformer- added more wording to title of project

8) Sigurd-Three Peaks-Hurricane-St. George 345kV line- removed from catalog, delayed beyond 2023

9) Standpipe 230 kV Synchronous Condenser- changed title to “Standpipe Substation

Construct New 230kV substation. Added more information about the project.

10) Table 6: Significant Generator Additions – this table has been updated from the 2012 submission to give a more accurate depiction of significant generator additions.

11) Table 8a - Future Generation Projects-Significant Generation Additions Table (PACE) - this table has been updated from the 2012 submission to give a more accurate depiction of future generator additions.

12) Table 8b -Future Generation Projects-Significant Generation Additions Table (PACW) - this table has been updated from the 2012 submission to give a more accurate depiction of future generator additions.

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13) Vantage-Pomona Heights 230kV Line- moved to the waiver portion of the report. Changed in service date to 2016.

14) Gateway West Transmission Project- added more detailed information and

changed some in- service dates.

15) Table 7- Planned Transmission Projects (Section B): Ben Lomond 345/138kV transformer- removed from table, in-service 2012 Carbon County System Upgrade - removed from table, in-service 2013 Casper substation- install 230/115kV transformer – new project added Clover substation- removed from table, in-service 2012 Copco Substation Increase- removed from report, in-service 2013 Fry substation, install 115 kV capacitors – removed from report, project is under 200kV Garland substation- Install 230kV 30 MVAr switched capacitor bank- new project added Line 3 Conversion project – removed from report, project is under 200kV Mid Valley substation- replace 345-138kV with 700 MVA transformers- new project added Red Butte/ St. George Double Circuit Line and 345/138 kV Transformer- changed name to “St. George substation-install 345/138kV transformer and expand yard”. Updated with detailed project information.

Syracuse- install 345/138kV #2 transformer- updated with detailed project information. Terminal transformer upgrade- removed from table, in-service 2012 Troutdale substation 230kV switchyard addition- updated with detailed project information. Union Gap 230/115 k V Increase in capacity, add a third 150 MVA transformer- updated with detailed project information. Whetstone 230/115 kV substation- updated with detailed project information. Yellowtail 230/138kV transformer- removed from report, delayed beyond 2023.

pacificorp 2014 annual progress report - final · 2014 annual progress report 5 iv. pinto add 3rd...

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