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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 8: Direct Assignment

Section 9: Schedule 11 Zonal

Section 10: Schedule 11 Regional


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 PTP Charge Schd1aTaPtpChg $177.60

480 x $0.37 = $177.60

PTP

Pri

ce

Ma

trix


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

http://www.spp.org/documents/13272/current bylaws and membership agreement tariff.pdf

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


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


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


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


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)


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


RC

per

inter

val

31


32

Calculate for all Qualified Generators within the Zone



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


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


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


40


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:



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:



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


Operating Reserve - Spinning Reserve Service

Schd6SuDirAssignChg


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.


Direct Assignment – Outputs


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


(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


with the monthly peak hour of the Zone

where the load is physically located. XML

files submitted by TOs:



Zonal

NITS

Charge

67


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


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 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


with the monthly peak hour of the Zone where

the load is physically located. XML files

submitted by TOs:



Zonal Resident

Load Charge

70



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


1


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


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


79Daily PTP Statement

Portal

Settlement Invoice

80

Portal

new settlements - southwest power pool training... · 2019. 2. 8. · cp zonal monthly x nits rate...

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