SETTLEMENTS
Transmission Training Toolkit
2016
TRANSMISSION: Charge Type Overview
October 2016
2
Terms and Acronyms
3
Terms and Acronyms
4
Transmission Data Flow
5
Transmission Schedules
6
Section 1: Schedule 1
Section 2: Schedule 1A
Section 3: Monthly Assessment
Section 4: Schedule 2
Section 5: Schedule 7
Section 6: Schedule 8
Section 7: Schedule 9
Section 8: Direct Assignment
Section 9: Schedule 11 Zonal
Section 10: Schedule 11 Regional
Section 11: Schedule 12
Section 12: Manual Adjustments
7
Contents
SCHEDULE 1Section 1
8
Schedule 1
Scheduling, System Control and Dispatch Service
Provides the scheduling and administering of the movement of power INTO, OUT OF, THROUGH or WITHIN SPP control areas.
Schedule 1 charges are calculated for all NITS and PTP Transmission Service Requests
I&W rates for Schedule 1 come from each Zone’s specific Tariff ATRR.
T&O the rate is an average off all Zone’s specific rates (SPP wide rate).
KEY POINTS:
Schedule 1 is calculated the same for Daily Point to Point (PTP) and Monthly Network (NITS) with one exception, NITS has no Off-Peak increment
*These rates are set by the Zone’s Specific tariffs
**Off Peak Charges and Revenues also exist for Schedule 1 PTP. Lower rates are used for off peak hours.
*** IS Integration has introduced additional through and out Schedule 1 business
9
Schedule 1 – Into-and-WithinInto-and-Within rates for Schedule 1 come from each Zone’s specific Tariff ATRR and will be displayed in the Zonal Sch1 tab in the RRR file as shown below
10
Schedule 1 –Through-and-OutThrough-and-Out rate is the average of all Zone specific rates, also known as SPP wide rate
11
.215 x $417.8 = $89.83
Schedule 1Scheduling Service
CP Zonal Monthly x NITS Rate = Schedule 1 NITS Charge
$89.83 x (-1) = -$89.83
Coincident Peak Load Schd1ScCoincidentPeakLoad .215 Zonal Current Month CP
NITS Rate Schd1ScNitsBillRt $417.8 Monthly Rate
NITS Charge Schd1ScNitsChg $89.83
Zonal ATRR Schd1ScAtrrByZoneByDay 1476845
Regional ATRR Schd1ScAtrrRegionwideTotalByDay 53970528
Prorata Share ATRR Prorata Share Schd 1 ATRR 0.027363916 Zonal / Regional ATRR (revenue share on T/O only
NITS Revenue Schd1ScNitsRev -$89.83 100%
Schedule 1 NITS Charge x (-1) = Schedule 1 NITS Revenue
NITSP
ric
e M
atr
ix
CP is the Customer or Zonal load
coincident with the monthly peak
hour of the Zone where the load is
physically located.BD
CT
Monthly NITS Statement
I/W
T/O
$89.83 x 0.027363916 x (-1) = -$2.46
Schedule 1 NITS Charge Prorata Share x (-1) = Schedule 1 NITS Revenue
12
Schedule 1Scheduling Service
Reserved Capacity x PTP Daily Rate = Schedule 1 PTP Charge
$33.18 x 0.027363916 X (-1) = -$-0.90793
Reserved Capacity PtpReservedCapacity 20 Zonal Current Month CP (Max)
PTP Daily Rate Schd1ScPtpNonhourlyBillRt $1.65901104
9
ATRR/MW/#months/#days
PTP Charge Schd1ScPtpChg $33.18
Zonal ATRR Schd1ScAtrrByZoneByDay $1,476,845
Regional ATRR Schd1ScAtrrRegionwideTotalByDay $53,970,528
Prorata Share ATRR Prorata Share Schd 1 ATRR 0.027363916 Zonal / Regional ATRR (revenue share on T/O only)
PTP Revenue Schd1ScPtpRev -$.90793 100% POD
20 x $1.659011049 = $33.18
Schedule 1 PTP Charge X Prorata Share x (-1) = Schedule 1 PTP Revenue
PTP
RR
R F
ILE
BD
CT
Daily PTP Statement
Assume MW is 2393
T/O
$33.18 x (-1) = -$-33.18
Schedule 1 PTP Charge x (-1)= Schedule 1 PTP RevenueI/W
13
SCHEDULE 1A Section 2
14
Schedule 1A
SPP Administrative Charge (Tariff Administration Charge)
An administrative charge applied to all transmission service under the SPP Tariff to cover SPP’s expenses related to administration of the Tariff. (Creates SPP Operating Budget which allows SPP to pay employees, purchase equipment, etc.)
Schedule 1A charges are calculated for all NITS TSRs
Schedule 1A PTP charges are calculated for I&W, as well as, T&O service
The SPP Region wide rate is applied to both PTP and NITS
Monthly Assessment is also a factor in forecasting 1A
15
SPP Administrative Charge
The Rate for Schedule 1A is set by SPP’s Board of Directors and is effective for a full calendar year. This rate is capped at .39 per SPP Open Access Transmission Tariff, Sixth Revised Volume No. 1,
Schedule 1-A Tariff Administration Service
Net Revenue Requirement/Forecasted Coincident Peak MWh = Rate.
Variation in either number can result in over or under recovery. Any over or under recovery is accounted for the following year so it can either increase or decrease the rate for the subsequent year.
Example: 2015 is $138.6 million/363,500,000 = $.39/MWh
16
Effective
Year Historical Rates
2016 $ 0.370
2015 $ 0.390
2014 $ 0.381
2013 $ 0.315
2012 $ 0.255
2011 $ 0.210
2010 $ 0.195
Schedule 1A (cont.)
https://www.oasis.oati.com/woa/docs/SWPP/SWPPdocs/2016_SPP_Admin_Fee_Breakout_Disclosure.pdf
Schedule 1-ATariff Administration
PYCP Zonal Average x Tariff Rate x Hours in Month = Schedule 1-A NITS Charge
Coincident Peak Load Schd1aTaCoincidentPeakLoad 1,644.808 OPPM Zonal Average PYCP
Tariff Rate Schd1aTaRt $0.37 Hourly Rate for 2016
Hours in month* Hours in Month = 31 Days x 24 Hours 744 Hours in August
Tariff NITS Charge Schd1aTaNitsChg $452,782.75
1,644.808 x $0.37 x 744 = $452,782.75
NITS
Pri
ce
Ma
trix
There is no Revenue allocation back to Transmission Owners, allocated to SPP - creates SPP’s Operating Budget
CP is the Customer or Zonal load coincident with
the monthly peak hour of the Zone where the load
is physically located. XML files submitted by TOs:
• Prior Month due by 25th
• Current Month due 2nd business day
BD
CT
Monthly NITS Statement
17
Schedule 1-ATariff Administration
PTP Reserved Capacity x Tariff Rate = Schedule 1-A PTP Charge
PTP Reserved Capacity PtpReservedCapacity 480 Sum of PtpReservedCapacity
Tariff Rate Schd1aTaRt $0.37 Hourly Rate for 2016
Tariff PTP Charge Schd1aTaPtpChg $177.60
480 x $0.37 = $177.60
PTP
Pri
ce
Ma
trix
There is no Revenue allocation back to Transmission Owners, allocated to SPP - creates SPP’s Operating Budget
BD
CT
Daily PTP Summary
Daily PTP Statement
Reserved Capacity amounts are based on
confirmed TSRs from OASIS feed into the
Settlement System.
18
MONTHLY ASSESSMENTSection 3
19
Monthly Assessment ChargeTariff Administration charges on Into-and-Within Point-To-Point (PTP) or Network Integrated Transmission Service (NITS) are credited back in this calculation.
• Applies the Schedule 1A rate to total footprint load at the Transmission Customer level
• Acts as a true up to all eligible Network Load* for a Transmission Customer
• Can be a charge or a credit
• Cannot result in a net credit
• Net credits are charged back two months in arrears through a Manual Adjustment
• Revenue is allocated to SPP (creates SPP Operating Budget)
• Assessed on each Member for the portion of their Member load eligible for service but not currently taking Network Integration Transmission Service or Point-to-Point Transmission Service under the SPP OATT
*Eligible network Load – Zonal load which includes grandfathered agreements. It is SPP’s way of accounting for GFA’s through transmission billing, otherwise GFA load would not be subject to Schedule 1A charges.
Monthly Assessment Charges are outlined in the SPP Bylaws, Section 8.4 Monthly Assessments
http://www.spp.org/documents/13272/current%20bylaws%20and%20membership%20agreement%20tariff.pdf
20
Monthly Assessment Charge
Monthly Assessment Load is:
Submitted by Transmission Owners and reconciled by Transmission Customers
Submitted to SPP Customer Relations\Settlements via signed document from the members on an annual basis via the Request Management System
Submitted for the previous calendar year by January 25 of each year
Remains static throughout the year
21
Monthly Assessment
Monthly Assessment Load x Tariff Rate x Hours in Month – PTP 1A Charge- NITS 1A Charge =
Monthly Assessment Charge
Monthly Assessment Load MonthlyAssessmentLoad_TcDpTp_M_QTY 3,460.061 Zonal Prior Calendar Year Average CP
Tariff Rate Schd1aTaRt $0.37 Hourly Rate for 2016
Hours in month* Hours in Month = 31 Days x 24 Hours 743 Hours in March (remember DST)
Credit for PTP 1A Charge Schd1aTaPtpIWChgSummary $192.77
Credit for NITS 1A Charge Schd1aTaNitsIWChgSummary $951,050.86
Monthly Assessment
Charge
MonthlyAssessmentChg $-38.26049
3,460.61 x $0.37 x 743 –$192.77-$951,050.86= $-38.26049
NITS
There is no Revenue allocation back to Transmission Owners, allocated to SPP - creates SPP’s Operating Budget
CP is the Customer or Zonal load
coincident with the monthly peak hour
of the Zone where the load is physically
located
BD
CT
Mo
nth
lyN
ITS
Sta
tem
en
t
The SPP
region wide
rate is
applied to
all
transactions
.
This rate is
applied to
the
Calendar
Year
Average of
the previous
year’s
monthly CP
data.
22
SCHEDULE 2Section 4
23
Schedule 2 -Reactive Supply and Voltage Control from Generation or Other Source ServiceThis service provides for the operation of generation facilities to produce or absorb reactive power in order to maintain transmission voltages within acceptable limits.
Schedule 2 Charges are calculated for all NITS and PTP TSRs, while Schedule 2 Revenue is calculated for all Qualified Generators*.
Schedule 2 Settlement
Billed on a monthly basis
Settled 2 months in arrears
Typically is not re-Settled
Separate Schedule 2 Statement
Mvars for Qualified Generators are compensable
When injecting MWs
+ / - Mvar are treated equally
Mvars beyond 95% Power Factor threshold
24*A Qualified Generator is a generator or a single generator that is part of a group of generators at a single
Point-of-Receipt that has been recognized by the Transmission Provider as meeting the criteria specified in
Section II to receive compensation under this Schedule 2.
Schedule 2 Process Flow
25
Input Data
26
Portal
Sa
mp
le X
ML
• Reactive Compensation Rate – static $2.26
• Mvar Data is submitted via the Portal by Meter Agents by the
15th of each month.
• Meter Data
INPUTS
Schedule 2 Process Flow
27
Schedule 2 Revenue- High LevelTransmission Customer Revenue is calculated first. Once the revenue has been calculated, allocations are formed based on a percentage of the total calculated revenue.
A monthly revenue compensation amount is calculated per generator based on MW and Mvar within the Dead Band (later explained).
Once the revenue compensation per generator is calculated, all generators RC is aggregated on the zonal level to determine rates.
Schedule 2 revenue is calculated for:
All Qualified Generators
All NITS and PTP TSRs
Schedule 2 Rates:
The rate of the Transmission Zone at the POD of TSR is applied to I/W
The SPP region wide rate is applied to T/O NITS
28
Schedule 2-REVENUEReactive Supply
Calculate Reactive Compensation Rate
Schd2RvRevByDayQG =
(-1) * Schd2RvCompRt * 𝑯{ IF MtrActGenQtyQG, H < 0, 𝐦𝐚𝐱[ 𝐚𝐛𝐬 (MtrActGenVarQtyQG, H ) -
𝐚𝐛𝐬 (MtrActGenQtyQG, H * ( 1 - 0.952)0.5 / .95) , 0 ] }
(-1) * Schd2RvCompRt *
𝑯{ IF MtrActGenQtyQG, H < 0,
𝐦𝐚𝐱[ 𝐚𝐛𝐬 (MtrActGenVarQtyQG, H ) -
𝐚𝐛𝐬 (MtrActGenQtyQG, H * ( 1 - 0.952)0.5 / .95) , 0 ] }
Translation: The Schedule 2 rate multiplied by
either 0 or the amount of Reactive Power outside
of the Dead Band that is greater than 0.
𝐚𝐛𝐬 (MtrActGenVarQtyQG, H ) - 𝐚𝐛𝐬 (MtrActGenQtyQG, H *
( 1 - 0.952)0.5 / .95) , 0 ] Translation: The amount of Reactive Power
outside the Dead Band.
Breaking it down
𝐚𝐛𝐬 (MtrActGenQtyQG, H * ( 1 - 0.952)0.5 / .95)
Translation: The amount of Reactive Power
inside the Dead Band and the amount the
Qualified Generator would have had to produce
or absorb to maintain a Power Factor (PF) of 0.95.
Current Reactive Compensation Rate- Constant rate of $2.26
per MVar
Dead Band -A contiguous range of Power Factor
operation where an hourly PF is greater than or equal to
0.95 (lead or lag).
CALCULATE REACTIVE COMPENSTATION
Reactive Power Inside Dead Band (RPID)- Constant
percentage of 0.32868
Power Factor Threshold - The power factor of a QG as measured
or determined by the integrated hourly MW and MVAr values at
its POI.
29
Calculate Reactive Compensation Rate
30
Step 1:
Obtain Mvar for all intervals of the day
Step 2:
Obtain the MW for all intervals of the day
Step 3:
Calculate the Power Factor per interval to determine if QG is
compensable.(Mvars beyond 95% Power Factor threshold)
IF(MWh>=0,"",ABS(MWh/(MV^2+MWh^2)^0.5))
Step 4:
Calculate Reactive Compensation- If PF > 95%, no RC; <95%, RC
Step 5:
Apply the static Reactive Power Inside the Dead Band percentage of
0.32868
Step 6:
Sum all interval RC values = Reactive Compensation (Schd2RvRevByDay)
CALCULATE REACTIVE COMPENSTATION
Meter Actual Amount MtrActGenQty -214.414 Mwh – 1st interval
Schedule 2 Rate Schd2RvPtpNonHourlyBill
Rt
$2.26 Constant Rate
Meter Variance Amount MtrActGenVarQty -78.939 Mvar – 1st interval
RPID .32868 Reactive Power Inside Dead band – Constant Amt calculated
by system
Reactive Compensation $-19.13 1st interval
Schedule 2 PTP Revenue Schd2RvRevByDay $-367.82 Sum for all intervals
Schedule 2- Reactive CompensationReactive Supply
=IF(MtrActGenQty >=0,"",ROUND(2.26*-1)*(MAX(ABS(MtrActGenVarQty)-(0.32868*(-1)*MtrActGenQty),0)),2))
BD
CT
Schedule 2 Statement
Represents one qualified generator QG.ABD.3
Power Factor- The power factor of a QG as measured or determined by the integrated
hourly MW and MVAr values at its POI. Varies by interval.
=IF(-214.41>=0,"",ROUND(2.26*-1)*(MAX(ABS(-78.939)-(0.32868*(-1)*-214.41),0)),2)) = $-19.13
Sum Schd2RvRevByDay for all intervals= $-367.82
Calculate for all QG within the Zone
CALCULATE REACTIVE COMPENSTATION
RC
per
inter
val
31
Calculate Reactive Compensation Rate
32
Calculate for all Qualified Generators within the Zone
CALCULATE REACTIVE COMPENSTATION
Schedule 2 Process Flow
33
Calculate Rates
34
Billing inputs submitted by transmission zones
PTP • Operating month Coincident Peak MWs
• Coincident Peak MWs are grossed up to include losses
NITS• Report Coincident Peaks for each network service customer
within zone
• Report Coincident Peaks for total zonal load used to calculate
Schedule 2 rates
CALCULATE RATES
Calculate RatesCalculate zonal rates
Monthly Rate ($/MW/Mo) = ZRC / Zonal Peak Demand
Weekly Rate ($/MW/Wk) = Monthly Rate times 12 / 52
Daily Off-Peak Rate ($/MW/Day) = Weekly Rate / 7
Daily On-Peak Rate ($/MW/Day) = Weekly Rate / 5
Hourly Off-Peak Rate ($/MW/Hr) = Daily Off-Peak Rate / 24
Hourly On-Peak Rate ($/MW/Hr) = Daily On-Peak Rate / 16
Through and Out rates determined by taking a simple average of the prior month zonal rates.
35
CALCULATE RATES
Schedule 2 Process Flow
36
Monthly Schedule 2 Statement (PTP Charge)
37
Portal
Schedule 2-PTP ChargeReactive Supply
PTP Reserved Capacity x Schedule 2 Rate = Schedule 2 PTP Charge
50 x $0.076616129 = $3.83
PTP
BD
CT
PTP Reserved Capacity PtpWeekMaxReservedCapacity 50 Max Reserved Capacity
Schedule 2 Rate Schd2RvPtpNonHourlyBillRt 0.076616129
Schedule 2 PTP Charge Schd2RvPtpChg $3.83
*PTP volumes are in MW
Price Matrix
Schedule 2 Statement
Capping for PTP:
• Determined by SPP Tariff
• Hourly service charge cannot exceed the daily service cost
• Daily service charge cannot exceed weekly service cost
38
Monthly Schedule 2 Statement (NITS Charge)
39
Portal
Schedule 2-ChargeReactive Supply
Schedule 2 Load x Schedule 2 NITS Rate= Schedule 2 NITS Charge
Schedule 2 CP Load Schd2RvCoincidentPeakLoad 124.715 Operating month CP MWs
Zonal Schedule 2 NITS Rate Schd2RvNitsBillRt $1.637433162
Schedule 2 NITS Charge Schd2RvNitsChg $204.21
124.715 x $1.637433162 = $204.21
NITS
BD
CT
Pri
ce
Ma
trix
Schedule 2 Statement
40
Schedule 2 Process Flow
41
Schedule 2-Allocate revenue (True-up)
Reactive SupplyBD
CT
Schedule 2 Revenue by Zone for TC Schd2RvTotalRevByZoneTc $-24,661.55 Reactive Revenue by zone by customer
Schedule 2 Charge by Zone Schd2RvTotalChgByZone $24,353.70 Calculated RC charge total for the zone
Schedule 2 Revenue by Zone Schd2RvTotalRevByZone $-24,745.24 Calculated RC revenue total for the zone
Revenue True-up factor Percentage -0.015822841 Zonal Charge/Zonal Revenue (% over or
under collection of RC)
Schedule 2 Revenue True-up Schd2RvRevTrueUpAdj $390.22 RC adjustment to correct for difference
between calculated revenue and calculated
charges
Schd2RvRevTrueUpAdj = Schd2RvTotalRevByZoneTc *
[ (Schd2RvTotalChgByZone / ((-1)*Schd2RvTotalRevByZone ) – 1
The difference between the total reactive revenue collected under the provisions of this
Schedule 2 and the total payments to the QG’s, by Zone, from the previous calendar year.
-$24,661.55*($24,353.7/((-1*$-24,745.24))-1) =$390.22
ALLOCATE REVENUE(TRUE-UP)
• Reactive Compensation for each zone is scaled up or down so
revenue equals charges 42
Zone 1
43
Process ExampleZONE Zone1 Zone 2 Zone 3 Zone 4 Zone 5 Zone 6 Zone 7 Zone 8
SCHEDULE 7Section 5
44
Schedule 7
Firm Point-to-Point Transmission Service
This service is for the firm receipt of capacity and energy at designated Point-of-Receipt and the transmission of such capacity and energy to designated Point-of-Delivery.
Calculated for Into-and-Within as well as Through-and-Out service. The rate of the Transmission Zone at the Point-of-Delivery is applied to Into-and-Within transactions; the Least Cost Interconnect methodology is used for Transmission Zones interconnected with the 1st tier Point-of-Delivery and is applied to Through-and-Out transactions.
Service Increments: Daily, Weekly, Monthly or Yearly
Service Periods: On-Peak, Off-Peak, Full Period
Rate Caps are applied
45
POD RATE
ABCD $65.65
LINK $21.50
SMAU $68.68
SMSU $55.98
I/W, uses LCI. In this example, the $21.50 rate
would be used
Schedule 7- ChargeFirm PTP Transmission Service
Reserved Capacity x Schedule 7 Rate= Schedule 7 PTP Charge
Reserved Capacity PtpReservedCapacity 20 Max MW of Reserved Capacity per OD
Schedule 7 Rate Schd7FirmPtpNonhourlyBillRt $66.56 Yearly Rate/12/# of days in period
Schedule 7 PTP Charge Schd7FirmPtpChg $1,331.20
20 x $66.56 = $1,331.20
Daily Statement
BD
CT
PTP
Also available in Price Matrix
RR
R F
ile
Att
ac
hm
en
t T
46
Schedule 7 - revenueFirm PTP Transmission Service
Schedule 7 Charge / 2 x Prorata Share *-1 = Schedule 7 PTP Revenue
$1,331.20 / 2 x $ 0.128971709 *-1 = $-85.84
PTP
BD
CT
Schedule 7 Charge Schd7FirmPtpChg $1,331.20
Zonal ATRR AtrrByDay $156,176,810 Zonal ATRR (used for Prorata Share)
Regional ATRR AtrrRegionwideTotalByDay $1,210,938,518 Regional ATRR (used for Prorata Share)
Schedule 7 PTP Revenue Schd7FirmPtpAtrrRev $-85.84 ATRR Ratio Revenue
Prorata Share ATRR 0.128971709 Zonal ATRR/Regional ATRR
MWM by Zone % .02710237 MWM Split % - Attachment S
Schedule 7 PTP MWM Revenue Schd7FirmPtpMwmRev $-18.04 MWM Revenue
Schedule 7 Charge / 2 x MWM by Zone *-1 = Schedule 7 PTP MWM Revenue
$1,331.20 / 2 x $ 0.02710237 *-1 = $-18.04
RR
R F
ile
Att
ac
hm
en
t H
CSWS MWMTOT
1.75 64.57
0.02710237
CSWS Prorata
Share MWMILE
Total Revenue $-103.88
47
SCHEDULE 8Section 6
48
Schedule 8Non-Firm Point-to-Point Transmission Service
This service is for the non-firm receipt of capacity and energy at designated Point-of-Receipt and the transmission of such capacity and energy to designated Point-of-Delivery.
Calculated for Into-and-Within as well as Through-and-Out service. The rate of the Transmission Zone at the Point-of-Delivery is applied to Into-and-Within transactions; the Least Cost Interconnect methodology is used for Transmission Zones interconnected with the 1st tier Point-of-Delivery and is applied to Through-and-Out transactions.
Service Increments: Hourly, Daily, Weekly or Monthly
Service Periods: On-Peak, Off-Peak, Full Period
Rate Caps are applied
49
Schedule 8- chargeNon-Firm PTP Transmission Service
Reserved Capacity x Schedule 8 Rate= Schedule 8 PTP Charge
Reserved Capacity PtpReservedCapacity 20 Reserved MW
Schedule 8 Non-Firm Rate Schd8NfPtpNonhourlyBillRt $65.65 Yearly Rate/# of days in period
Schedule 8 Non-Firm PTP Charge Schd8NfPtpChg $1,313.00
20 x $65.65 = $1,313.00
Daily Statement
BD
CT
RR
R F
ile
Att
ac
hm
en
t T
PTP
Also available in Price Matrix
50
Schedule 8 - revenueNon-Firm PTP Transmission Service
Schedule 8 PTP Charge / 2 x Prorata Share *-1 = Schedule 8 PTP Revenue
$1,313.00 / 2 x $ 0.128971709 *-1 = $-84.67
PTP
BD
CT
Schedule 8 PTP Charge / 2 x MWM by Zone *-1 = Schedule 8 PTP MWM Revenue
$1,313.00 / 2 x $ 0.02710237 *-1 = $-17.79
RR
R F
ile
Att
ac
hm
en
t H
CSWS MWMTOT
1.75 64.57
0.02710237
CSWS Prorata
Share MWMILE
Schedule 7 Charge Schd7FirmPtpChg $1,313.00
Zonal ATRR AtrrByDay $156,176,810 Zonal ATRR (used for Prorata Share)
Regional ATRR AtrrRegionwideTotalByDay $1,210,938,518 Regional ATRR (used for Prorata Share)
Schedule 7 PTP Revenue Schd7FirmPtpAtrrRev $-84.67 ATRR Ratio Revenue
Prorata Share ATRR 0.128971709 Zonal ATRR/Regional ATRR
MWM by Zone % .02710237 MWM Split % - Attachment S
Schedule 7 PTP MWM Revenue Schd7FirmPtpMwmRev $-17.79 MWM Revenue
Total Revenue $-102.46
51
SCHEDULE 9
Section 7
52
Network Integration Transmission Service:
• Allows the Network Customer to integrate, economically dispatch and regulate its current and planned Network resources.
• Is calculated for all NITS TSRs as a ratio share of the monthly ATRR. In most Transmission Zones the quantity determinant is the Calendar Year Average of the previous year’s monthly CP data.
Exceptions:
Zone 1 and Zone 10, the Schedule 9 Charges are calculated differently (rate multiplied by current month CP usage per zonal load)
Schedule 9 is not assessed to Point to Point or GFA
Schedule 9-Network Integration Transmission Service
53
153.525/4,697.591 x ($271,161,716 X 1/12) = $738,500.91
Schedule 9 - CHARGENetwork Service
PYCP Load/Zonal PYCP x (ATRR x 1/12) NITS Rate = Schedule 9 NITS Charge
Coincident Peak Load Schd9NitsCoincidentPeakLoad 153.525 UGPM Zonal Schedule 9 Load
NITS Zonal CP Load Schd9NitsZonalCpLoad 4,697.591 UGPM Zonal Average PYCP
Load Ratio Share0.032681645
Not in XML (zonal load/PYCP)
NITS Zonal ATRR Schd9NitsAnnTransRevReqByXO $271,161,716 UGPM ATRR – TO formula rate –
Attachment H
NITS Charge Schd9NitsChg $738,500.91
Att
ac
hm
en
t H
BD
CT
CP is the Customer or Zonal load coincident
with the monthly peak hour of the Zone where
the load is physically located. XML files
submitted by TOs:
• Prior Month due by 25th
• Current Month due 2nd business day
NITS
Represents one TSR
54
($138,325,368/$27,161,716) x $738500.91 *-1 = $-376,725.05
Schedule 9 - REVENUENetwork Service
(TO ATRR/Zonal ATRR) x Schedule 9 NITS Charge *-1= Schedule 9 NITS Revenue
NITS Zonal ATRR Schd9NitsAnnTransRevReqByXO $271,161,716 UGPM ATRR – TO formula rate –
Attachment H
TO ATRR Schd9NitsAnnualTransRevReq 138,325,368.00
ATRR Ratio Share 0.51 TO ATRR/Zonal ATRR
NITS Charge Schd9NitsChg $738,500.91
Owner Revenue Schd9NitsRev $-376,725.05 51% to (Owner)
Att
ac
hm
en
t H
BD
CT
CP is the Customer or Zonal load coincident with
the monthly peak hour of the Zone where the
load is physically located. XML files submitted
by TOs:
• Prior Month due by 25th
• Current Month due 2nd business day
NITS
Represents one TSR
55
DIRECT ASSIGNMENTSection 8
56
Direct Assignment
Direct Assignment is a mechanism to pass through charges from a Transmission Owner to a Transmission Customer
Transmission Owners submit monthly Direct Assignment xml via the portal for NITS billing
* Due by noon on the 25th of the month for Resettlements
* Due by noon on the 2nd business day of the month for Initial Settlements
57SPP does not perform any calculations for Direct Assignment
Direct Assignment - InputsXML Tag Names for Inputs submitted by Transmission Owners
58
* In June, 2016, we added two new Direct
Assignment Charge Types
• Generation Imbalance
• Energy Imbalance
CHARGETYPEDESCRIPTION
TC_MO_ANC_3_REG_AMT
TC_MO_ANC_5_SPIN_AMT
TC_MO_ANC_6_SUPPL_AMT
DISTRIBUTION_FACILITIES_DIRECT_ASSIGNMENT_AMT
TRANSMISSION_FACILITIES_DIRECT_ASSIGNMENT_AMT
POWER_FACTOR_AMT
METERING_AMT
SYSTEM_UPGRADE_AMT
MISCELLANEOUS_ADJUSTMENT_AMT
REQUESTED_UPGRADE_AMT
GEN_IMBALANCE_DIRECT_ASSIGNMENT_AMT*
ENERGY_IMBALANCE_DIRECT_ASSIGNMENT_AMT*
The Distribution Facilities Direct Assignment Amount is just one example Direct Assignment Charges
Input
XM
L E
xam
ple
CHARGE_NAME DESCRIPTION
AdjMiscAdjustmentDirAssignChg Direct assignment charge passed on by Transmission Owner for Miscellaneous charge.
DistFacilitiesDirAssignChg Direct assignment charge passed on by Transmission Owner for Distribution Facilities.
MeteringDirAssignChg Direct assignment charge passed on by Transmission Owner for Metering.
PowerFactorCorrectDirAssignChg Direct assignment charge passed on by Transmission Owner for Power Factor.
Schd3RfDirAssignChg
Direct assignment charge passed on by Transmission Owner for Schedule 3 or
Regulation and Frequency Response Service .
Schd5SpDirAssignChg
Direct assignment charge passed on by Transmission Owner for Schedule 5 or
Operating Reserve - Spinning Reserve Service
Schd6SuDirAssignChg
Direct assignment charge passed on by Transmission Owner for Schedule 6 or
Operating Reserve - Supplemental Reserve Service
TransFacilitiesDirAssignChg
Direct assignment charge passed on by Transmission Owner for Transmission Facilities
Charge.
59
Charge Types - Direct Assignment Charges
Settlement Statement
60
Charge Types - Direct Assignment Revenue
CHARGE_NAME DESCRIPTION
DistFacilitiesDirAssignRev Direct assignment Revenue passed on by Transmission Owner for Distribution Facilities.
FacilitiesUpgradeDirAssignRev Direct assignment revenue passed on by Transmission Owner for Transmission Facilities Charge.
MeteringDirAssignRev Direct assignment revenue passed on by Transmission Owner for Metering.
PowerFactorCorrectDirAssignRev Direct assignment revenue passed on by Transmission Owner for Power Factor.
Schd3RfDirAssignRev
Direct assignment Revenue passed on by Transmission Owner for Schedule 3 or Regulation and
Frequency Response Service .
Schd5SpDirAssignRev
Direct assignment Revenue passed on by Transmission Owner for Schedule 5 or Operating
Reserve - Spinning Reserve Service
Schd6SuDirAssignRev
Direct assignment Revenue passed on by Transmission Owner for Schedule 6 or Operating
Reserve - Supplemental Reserve Service
TransFacilitiesDirAssignRev Direct assignment revenue passed on by Transmission Owner for Transmission Facilities Charge.
Settlement Statement
Direct Assignment – Outputs
Settlement Statement
Example Settlement Statement
61
1258789
SCHEDULE 11 ZONALSection 9
62
Schedule 11 Zonal Calculation Flow
63
Schedule 11 ZonalFirm PTP Transmission Service
Max (On-Peak)Reserved Capacity x Schedule 11 (Non-Firm On-Peak) Rate= Schedule 11 Zonal
PTP Charge
Reserved Capacity (On-Peak) MAXPtpReservedCapacity 20
Schedule 11 Rate Schd11NonFirmPtpNonhourlyBillRt $1.3370
Schedule 11 PTP Charge Schd11FirmPtpChg $26.74
20 x $1.3370 = $26.74
Schedule 11 Zonal Data
BD
CT
Pri
ce
Ma
trix
PTP
Charge
Also available in RRR
64
Schedule 11 ZonalFirm PTP Transmission Service
PTP
Revenue
Allocation
BD
CT
RR
R F
ile
Att
ac
hm
en
t H
From Brightline tab: Projects
after 10/1/2015.
1 Total ITCM TO Upgrades in NPPD Zone $6,125
2 Total All TO Upgrades in NPPD Zone $11,715,943
3
Pre Bal Port and Brightline Load Ratio Share (#1 /
#2) 0.000522792
4 11 Zonal Charge $26.74
5 Total ITCM TO Upgrades in NPPD Zone $6,125
6
Total All TO Upgrades in NPPD Zone Less
Balance Portfolio Transfers Plus Brightline $3,412,477.82
7 Post Bal Port Load Ratio Share (#5 / #6) 0.001794883
8
NPPD TO Schedule 11 Zonal Revenue (#4 * #6)
*-1 -$0.05
What about the rest of the charge? This calculation will be
performed in the same way for all other TO’s who built projects
in GRDA Zone. The total of the Schedule 11 Zonal Revenue will
equal the Schedule 11 Zonal Charge.
65
Schedule 11 ZonalNetwork Service
Zonal
NITS
Charge
Why are there so many Load numbers? These
are the load numbers currently configured in our
settlements system to be used in the calculation
if there is a tariff change. Currently we only use
the Prior Year Coincident Peak Average.
This is a general overview of the calculation for
Schedule 11 Zonal Charge.
66
(668.4/685.83) x ($3,813,270 X (1/12)) = $309,696.48
Schedule 11 ZonalNetwork Service
(PYCP Load/Zonal Resident Load) x (ATRR x 1/12) = Schedule 11 Zonal NITS Charge
Coincident Peak Load Schd11BpzCoincidentPeakLoad 668.4 GRDX Zonal Schedule 11 Load
NITS Zonal CP Load ZonalResidentLoad 685.83 GRDA Zonal Average PYCP
GRDA LRS Schd11BpzCpLoadRatioShare 0.974585539 (zonal load/PYCP)
NITS ATRR Schd11BpzNitsBillRevReq $3,813,270 GRDA ATRR – TO formula rate – Balance
Portfolio Transfers
NITS Charge Schd11BpzNitsChg $309,696.48 Charge To GRDX TC
Ba
l P
ort
Tra
nsfe
r
BD
CT
CP is the Customer or Zonal load coincident
with the monthly peak hour of the Zone
where the load is physically located. XML
files submitted by TOs:
• Prior Month due by 25th
• Current Month due 2nd business day
Zonal
NITS
Charge
67
Schedule 11 ZonalNetwork Service
1
Total GRDA TO Upgrades in GRDA
Zone (4,874,836 + 649,333) $5,524,169
2 Total All TO Upgrades in GRDA Zone $6,671,984
3
Pre Balance Portfolio Transfer LRS
(#1 / #2) 0.827964965
4 11 Zonal Charge (from slide 9) $309,696.48
5
Total GRDA TO Upgrades in GRDA
Zone Less Balance Portfolio Transfers
( #1 – 2,858,714)
$2,665,454.8
6
6
Total All TO Upgrades in GRDA Zone
Less Balance Portfolio Transfers
(#2 – 2,858,714)
$3,813,269.8
6
7
Post Bal Port Load Ratio Share (#5 /
#6) 0.698994553
8
GRDA TO Schedule 11 Zonal
Revenue (#4 * #7) $216,476.15
Ba
se
Pla
n R
ev.
Re
q. A
llo
c. -
RR
R
What do the numbers mean? TO’s including GRDA built projects
which allowed GRDA to have a certain level of Network Capacity.
So, TC’s within GRDA zone pay the TO’s who built projects which
enhanced the transmission system in the GRDA Transmission
zone.
Zonal NITS
Revenue
What about the rest of the charge? This
calculation will be performed in the same way
for all other TO’s who built projects in GRDA
Zone. The total of the Schedule 11 Zonal
Revenue will equal the Schedule 11 Zonal
Charge.
68
Schedule 11 ZonalNetwork Service
This is a general overview of the calculation for
Schedule 11 Zonal Resident Load Charge.
Zonal Resident
Load Charge
69
(668.4/685.83) x ($3,813,270 X (1/12)) = $8,076.02
Schedule 11 ZonalResident Load
((Zonal Resident Load/PYCP Load)-1) x (ATRR x 1/12) = Zonal Resident Load Charge
Coincident Peak Load Schd11BpzCoincidentPeakLoad 668.4 GRDX Zonal Schedule 11 Load
NITS Zonal CP Load ZonalResidentLoad 685.83 GRDA Zonal Average PYCP
GRDA LRS Schd11BpzCpLoadRatioShare 0.025414461 Not in XML (zonal load/PYCP)
NITS ATRR Schd11BpzNitsBillRevReq $3,813,270 GRDA ATRR – TO formula rate – Balance
Portfolio Transfers
NITS Charge Zonal Resident Load Nits Charge $8,076.02 Charge To GRDX TC
Ba
l P
ort
Tra
nsfe
r
BD
CT
CP is the Customer or Zonal load coincident
with the monthly peak hour of the Zone where
the load is physically located. XML files
submitted by TOs:
• Prior Month due by 25th
• Current Month due 2nd business day
Zonal Resident
Load Charge
70
Schedule 11 ZonalNetwork Service
This is a general overview of the calculation for
Schedule 11 Zonal Resident Load Revenue.
What are the Pennies and Pp (Pre Penny) determinants? For
the purposes of this training they are not important. But in SPP
uses them to correct for rounding in our system. The calculation
logic allocates the pennies and parts of pennies based on the
direction outlined in the SPP OATT.
Zonal Resident
Load Revenue
71
Schedule 11 ZonalNetwork Service
1
Total GRDA TO Upgrades in GRDA
Zone (4,874,836 + 649,333) $5,524,169
2 Total All TO Upgrades in GRDA Zone $6,671,984
3
Pre Balance Portfolio Transfer LRS
(#1 / #2) 0.827964965
4 Zonal Resident Load Charge $8,076.02
5
Total GRDA TO Upgrades in GRDA
Zone Less Balance Portfolio Transfers
( #1 – 2,858,714)
$2,665,454.8
6
6
Total All TO Upgrades in GRDA Zone
Less Balance Portfolio Transfers
(#2 – 2,858,714)
$3,813,269.8
6
7
Post Bal Port Load Ratio Share (#5 /
#6) 0.698994553
8
GRDA TO Schedule 11 Zonal Revenue
(#4 * #7) -$5,645.09
Ba
se
Pla
n R
ev.
Re
q. A
llo
c. -
RR
R
What do the numbers mean? TO’s including GRDA built projects
which allowed GRDA to have a certain level of Network Capacity.
So, TC’s within GRDA zone pay the TO’s who built projects which
enhanced the transmission system in the GRDA Transmission
zone.
Zonal Resident
Load Revenue
Key: This calculation will be performed in the same
way for all other TO’s who built projects in GRDA Zone.
The total of the Schedule 11 Zonal Revenue will equal
the Schedule 11 Zonal Charge.
72
SCHEDULE 12Section 10
73
Schedule 12FERC ASSESSMENT
Scheduled Energy x FERC Rate= Schedule 12 NITS Charge
Current Month Schedule 12 Load Schd12FercPtpIWNitsGfaLoad 952180.985 Zonal Scheduled Energy
FERC Rate Schd12FercRt $0.0642509735 Hourly Rate for 2016
Schedule 12 NITS Charge Schd12FercPtpIWNitsGfaChg $61,178.56
952180.985 x $0.0642509735 = $61,178.56
NITSP
ric
e M
atr
ix
There is no Revenue allocation back to Transmission Owners, allocated to SPP - FERC Fee recovery
BD
CT
74
Schedule 12Tariff Administration
Scheduled Energy x FERC Rate = Schedule 12 PTP Charge
2980 x $0.0642509735 = $191.70
PTP
Pri
ce
Ma
trix
There is no Revenue allocation back to Transmission Owners, allocated to SPP –FERC Fee Recovery
BD
CT
Point to Point Scheduled Energy PtpScheduledEnergy 2980 Sum of PTP Scheduled Energy
FERC Rate Schd12FercRt $0.0642509735 Hourly Rate for 2016
Schedule 12 PTP Charge Schd12FercPtpTOChg $191.47
*PTP volumes are in MWh
75
MANUAL ADJUSTMENTSSection 11
76
Due to the complex nature of some of the Transmission charges, not
all charges are handled programmatically within the system and must
be entered via manual adjustment.
• Can start out as Manual Adjustments and with system
enhancements be incorporated into the system
• Can be applied on any day of the month
Manual Adjustments - Reasons
77
Miscellaneous Recurring Adjustments
Network Adjustments
Encompass special situations like NITS billing of Through-and-Out transactions
Unreserved Capacity
Upgrade Adjustments Supplied by Transmission Service Studies
• Encompass billing for upgrades, via Base Rate or Direct
Assignment, not schedule 11
Miscellaneous Non Recurring Adjustments
Manual Adjustments - Types
78
Settlement Statement
79Daily PTP Statement
Portal
Settlement Invoice
80
Portal