via electronic filing · 2013. 7. 17. · the honorable kimberly d. bose july 17, 2013 page 3...

July 17, 2013

VIA ELECTRONIC FILING

The Honorable Kimberly D. Bose

Secretary

Federal Energy Regulatory Commission

888 First Street, N.E.

Washington, D.C. 20426

Re: Southwest Power Pool, Inc., Docket No. ER13-_____-000

Submission of Tariff Revisions to Clarify Attachment T References for

Balanced Portfolio Reallocation

Dear Secretary Bose:

Pursuant to Section 205 of the Federal Power Act, 16 U.S.C. 824d (2000) (“FPA”),

and Section 35.13 of the Federal Energy Regulatory Commission’s (“Commission”)

Regulations, 18 C.F.R. § 35.13, Southwest Power Pool, Inc. (“SPP”) submits

revisions to its Open Access Transmission Tariff (“Tariff”)1 to modify Attachment T

to clarify that rates for Point-To-Point Transmission Service (“PTP”) specified in

Attachment T shall be adjusted to recognize Zonal Annual Transmission Revenue

Requirement(s) (“Zonal ATRRs”) which are reallocated pursuant to the Balanced

Portfolio in accordance with Section IV.A of Attachment J. SPP requests an effective

date of September 31, 2013 for the revisions proposed in this filing.

I. BACKGROUND

A. SPP

SPP is a Commission-approved Regional Transmission Organization (“RTO”).2 It is

an Arkansas non-profit corporation with its principle place of business in Little Rock,

Arkansas. SPP has 72 Members, including 14 investor-owned utilities, 11 municipal

systems, 13 generation and transmission cooperatives, 4 state agencies, 11

independent power producers, 10 power marketers and 9 independent transmission

companies. As an RTO, SPP administers open access Transmission Service on a

regional basis over approximately 48,930 miles of transmission lines covering

1 Southwest Power Pool, Inc., FERC Electric Tariff, Sixth Revised Volume No. 1.

2 Southwest Power Pool, Inc., 109 FERC ¶ 61,009 (2004), order on reh’g, 110 FERC ¶

61,137 (2005).


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portions of Arkansas, Kansas, Louisiana, Missouri, Nebraska, New Mexico,

Oklahoma, and Texas, across the facilities of SPP’s Transmission Owners,3

administers a centralized real-time energy imbalance service market,4 and has

received conditional Commission approval to implement day ahead and real-time

energy and operating reserve markets with locational marginal pricing and market-

based congestion management,5 which SPP plans to commence in March 2014.

The Tariff specifies zonal rates for transmission service. For service to load located

within the SPP region, the transmission rates are based on the Annual Transmission

Revenue Requirement (“ATRR”) for the host Zone (as defined in the Tariff) within

which the load is located.6 The Zonal ATRR for each pricing Zone for network

service is set out in Attachment H of the Tariff. The rates for PTP, which are based

on the ATRR in Attachment H, are set forth in Attachment T. Additionally, SPP

assesses Base Line Zonal Charges and Region-wide Charges to PTP customers for

recovery of costs for Base Plan Upgrades pursuant to Article V, Section 42 of the

Tariff.7

B. Balanced Portfolio Related Filings

On August 15, 2008, SPP submitted revisions to the Tariff to add a Balanced

Portfolio cost allocation process for economic planning upgrades, including a

regional postage-stamp rate design for recovery of the costs of such upgrades.8 The

Balanced Portfolio process described in the Balanced Portfolio Filing was the result

of extensive stakeholder process wherein the Balanced Portfolio process was

3 See Sw. Power Pool, Inc., 89 FERC ¶ 61,084 (1999); Sw. Power Pool, Inc., 86 FERC

¶ 61,090 (1999); Sw. Power Pool, Inc., 82 FERC ¶ 61,267, order on reh’g, 85 FERC

¶ 61,031 (1998).

4 Sw. Power Pool, Inc., 118 FERC ¶ 61,055 (2007) (accepting SPP’s Market Readiness

Certification and authorizing a February 1, 2007 start date for the EIS Market).

5 Sw. Power Pool, Inc., 141 FERC ¶ 61,048 (2012) (conditionally accepting SPP’s

“Integrated Marketplace” proposal).

6 See Tariff at Schedules 7-9.

7 See Tariff, Article V, § 42 (“Base Plan Zonal Charges and Region-wide Charges shall

be determined in accordance with Schedule 11 and assessed to Transmission

Customers taking [PTP] under the Tariff”).

8 Submission of Revisions to Open Access Transmission Tariff to Add “Balanced

Portfolio” Cost Allocation Process for Economic Planning Upgrades of Southwest

Power Pool, Inc., Docket No. ER08-1419-000 (“Balanced Portfolio Filing”) (August

15, 2008).


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developed over a two year period with overwhelming support from SPP’s

stakeholders and state regulatory commissions.9 The Commission accepted the

Balanced Portfolio Filing on October 16, 2008.10

On August 2, 2012, as amended on September 26, 2012, SPP submitted revisions to

Attachments H and T of the Tariff to update the revenue requirements and associated

rates in order to implement the initial reallocation of revenue requirements pursuant

to the Balanced Portfolio cost allocation methodology.11

The Commission approved

the initial reallocation of revenue requirements on November 20, 2012.12

As a result

of the implementation of the initial reallocation of revenue requirements pursuant to

the November 20 Order, Zonal PTP rates utilized in settlements have been adjusted

consistent with the approved reallocations.

On April 30, 2013, SPP submitted revisions to its Tariff to modify Attachment L,

Section III to clarify that rates for PTP specified in Attachment T shall be adjusted to

recognize Zonal ATRRs which are reallocated pursuant to the Balanced Portfolio in

accordance with Section IV.A of Attachment J, and the associated revenues shall be

distributed to those Transmission Owner(s) that otherwise would receive less revenue

as a result of the Balanced Portfolio reallocation.13

In the April 30 Filing, SPP

proposed to clarify the revenue distribution methodology currently being utilized with

respect to the Zonal ATRR portion of the reallocated revenue requirement to ensure

that each Zone recovers its due revenue requirement, and that no Zone derives a

revenue windfall resultant from the reallocation of Zonal to Region-wide cost

recovery. The Commission accepted the April 30 Filing on June 12, 2013.14

9 See Balanced Portfolio Filing at 2.

10 Sw. Power Pool, Inc., 125 FERC ¶ 61,054 (2008).

11 Submission of Tariff Revisions to Implement the Initial Reallocation of Revenue

Requirements Pursuant to Attachments J and O of Southwest Power Pool, Inc.,

Docket ER12-2387-000 (Aug. 2, 2012). See also Motion to Amend Filing and

Amend Answer of Southwest Power Pool, Inc., Docket ER12-2397-002 (Sept. 26,

2012).

12 Sw. Power Pool, Inc., 141 FERC ¶ 61,149 (2012) (“November 20 Order).

13 Submission of Tariff Revisions to Incorporate Revenue Distribution with Balanced

Portfolio Reallocation of Southwest Power Pool, Inc., Docket No. ER13-1379-000

(April 30, 2013) (“April 30 Filing”).

14 See Sw. Power Pool, Inc., Letter Order, Docket No. ER13-1379-000 (June 12, 2013)

(“June 12 Order”).


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II. DESCRIPTION OF TARIFF REVISIONS

With this filing, SPP proposes to modify Attachment T to include the following

language in each zonal rate sheet for PTP:15

Balanced Portfolio Reallocation Adjustment of Point-To-Point Rates

Rates for Point-To-Point Transmission Service specified in this Attachment T

shall be adjusted to reflect any amount reallocated from the Zonal Annual

Transmission Revenue Requirement in accordance with Section IV.A of

Attachment J. The rates, including any applicable reallocation adjustment,

shall be set forth in the RRR File posted on the SPP website.16

The proposed language revises the description of the zonal PTP rates to recognize the

potential adjustments to PTP rates due to Balanced Portfolio reallocations. In the

event that a Balanced Portfolio reallocation amount is large enough to require

reallocation from the Zonal ATRR, the addition of the proposed language above will

provide clarity how PTP rates shall be adjusted in accordance with Section IV.A of

Attachment J of the Tariff. Further, the proposed language also directs the reader to

the rates, including any applicable reallocation adjustments, which are posted in the

15

The modifications to the rate sheets for PTP in Attachment T shall be applicable to

the SPP Transmission Owners in the following Zones: American Electric Power-

West; City Utilities of Springfield, Missouri; The Empire District Electric Company;

Grand River Dam Authority; Kansas City Power & Light Company; KCP&L Greater

Missouri Operations Company, Lincoln Electric System, Mid-Kansas Electric

Company, LLC; Midwest Energy, Inc.; Nebraska Public Power District; Oklahoma

Gas and Electric Company; Omaha Public Power District; Southwestern Public

Service Company; Sunflower Electric Power Corporation; Westar Energy, Inc.

(“Westar”); Western Farmer Electric Cooperative. The Tariff modifications proposed

herein are not applicable to the PTP rates for the Southwestern Power Administration

Zone.

16 See Tariff revision Attachment T.


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RRR File.17

The proposed Tariff language ensures consistency with the modifications

accepted by the Commission in the November 20 and June 12 Orders discussed

above.

Additionally, SPP proposes additional revisions to the PTP rate sheet for the Westar

Zone to delete a redundant reference to Section IV.A of Attachment J.18

With the

inclusion of the language proposed in this filing, as described above, the existing

reference to Section IV.A of Attachment J in line item #1 for Firm PTP is no longer

necessary, and creates a redundancy if not deleted. Therefore, SPP proposes to delete

the reference. Deletion of this reference will not impact the rate, as recognition of

Section IV.A of Attachment J is being added with this filing and accomplishes the

same purpose of the deleted language.

III. JUSTIFICATION FOR TARIFF REVISIONS

The Tariff provisions submitted herein do not change the Commission-approved

methodology or underlying purpose of the Balanced Portfolio, or otherwise impact

rates that are currently charged to Transmission Customers under the Tariff. The

intent of Balanced Portfolio reallocation of revenue requirements is to reduce the

zonal cost of transmission, and not to impact revenue to the Transmission Owner. To

that end, the Tariff language proposed herein revises the description of the zonal PTP

rates to recognize the potential adjustments to PTP rates due to Balanced Portfolio

reallocations. The inclusion of the proposed Tariff language for all SPP zonal rate

descriptions in Attachment T is just and reasonable because the proposed Tariff

language provides the clarifications that adjustment are applicable to all SPP zonal

17

See Tariff at R- Definitions (The RRR File is “A file posted on the SPP website as a

reference to : (i) Annual Transmission Revenue Requirements (ATTRs) for Network

Integration Transmission Service, as referenced in Attachment H of this Tariff; (ii)

Base Plan ATRR allocation; (iii) allocation factors for Base Plan funded projects; (iv)

notes on the calculation of Base Plan ATRR amounts on a Region-wide and Zonal

basis; (v) ATRR reallocation for Balanced Portfolio projects; (vi) the calculation of

Base Plan Point-To-Point Transmission Service rates on a Region-wide and Zonal

basis in accordance with Schedule 11; and (vii) the rates for Point-To-Point

Transmission Service as referenced in Attachment T in accordance with Schedules 7

and 8.”). The Commission approved the use of the RRR File in Docket NO. ER12-

74-000 (Dec. 5, 2011) (approving the use of the RRR File to post updates to ATRR,

Base Plan ATRR allocation, etc., consistent with the definition of the RRR File).

18 With the exception of the terms and conditions provided in existing Attachment T for

the Westar Zone, no other Zonal rate descriptions in existing Attachment T provides

for adjustment of the zonal PTP rates in the event that the Balanced Portfolio

reallocation impacts the Zonal ATRR.


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PTP rates19

in the event that the Balanced Portfolio reallocation impacts the Zonal

ATRR.

With the exception of the Westar Zone, the existing Tariff does not recognize the

adjustment of zonal PTP rates based on the Balanced Portfolio reallocation for any

other SPP Zone. The Tariff modifications proposed herein remedy that gap.

Therefore, in the event that a Balanced Portfolio reallocation amount is large enough

to require reallocation from the Zonal ATRR, the addition of the proposed language

above will provide clarity how PTP rates shall be adjusted in accordance with Section

IV.A of Attachment J of the Tariff. Additionally, this clarification is necessary to

ensure consistency with the collateral Tariff revisions implemented in the November

20 and June 12 Orders.

The Tariff revisions proposed in this filing are the result of SPP’s stakeholder process

and were developed through the Regional Tariff Working Group (“RTWG”) to

provide further clarity to the Tariff regarding Balanced Portfolio reallocations.

Specifically, the proposed Tariff modifications provide that rates for PTP specified in

the Zonal descriptions of Attachment T shall be adjusted to reflect the reallocations of

Zonal ATRR pursuant to the Balanced Portfolio and in accordance with Section IV.A

of Attachment J. This clarification will support SPP’s revenue distribution under the

reallocations which started in 2012. At its meeting held on March 6, 2013, the RTWG

unanimously approved the Tariff revisions.20

At its April 16-17, 2013 meeting, the

Markets and Operations Policy Committee approved the proposed Tariff language

and recommended to the SPP Board of Directors that the Tariff revisions be

approved.21

The SPP Board of Directors approved the proposed Tariff revisions for

inclusion in the Tariff on April 30, 2013.22

As stated previously, the Tariff revisions proposed by SPP herein are the result of the

stakeholder process, and were approved by the SPP Board of Directors. While SPP

19

See infra n. 15. The proposed Tariff revisions in this filing apply to all SPP Zones,

with the exception of the Southwestern Power Administration.

20 See Agenda Item No. 3 at:

http://www.spp.org/publications/RTWG%20Meerting%20Mintues%20and%20Attac

hments%20-%20March%206%20-%207,%202013.pdf.

21 See Meeting Minutes at Summary of Actions Taken, Agenda Item 1 (n). The MOPC

meeting minutes can be found here:

http://www.spp.org/publications/MOPC%20Minutes%20&%20AttachmentsApril%2

016-17,%202013.pdf.

22 See Approved Consent Agenda Items 1(b)(iii) at 1. The SPP Board of Directors

meeting minutes can be found here:

http://www.spp.org/publications/BOD043013.pdf

http://www.spp.org/publications/RTWG%20Meerting%20Mintues%20and%20Attachments%20-%20March%206%20-%207,%202013.pdf

http://www.spp.org/publications/RTWG%20Meerting%20Mintues%20and%20Attachments%20-%20March%206%20-%207,%202013.pdf

http://www.spp.org/publications/MOPC%20Minutes%20&%20AttachmentsApril%2016-17,%202013.pdf

http://www.spp.org/publications/MOPC%20Minutes%20&%20AttachmentsApril%2016-17,%202013.pdf

http://www.spp.org/publications/BOD043013.pdf


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recognizes that stakeholder approval does not by itself cause a filing to be just and

reasonable, SPP requests that the Commission extend appropriate deference to the

wishes of SPP’s stakeholders, consistent with Commission precedent.23

Further, the

addition of this language will provide clarity to the Tariff. For these reasons, SPP

requests the Commission find these proposed Tariff modifications to be just and

reasonable and accept the Tariff revisions included in this filing and grant an effective

date of September 31, 2013.

IV. EFFECTIVE DATE

SPP requests that the Commission accept the proposed revisions to the Tariff to

become effective September 31, 2013, which is not less than 60 days, or more than

120 days, after the submission of this filing as required by the Commission.24

23

The Commission has previously recognized that provisions approved through

RTO stakeholder processes are due deference. See Sw. Power Pool, Inc., 127

FERC ¶ 61,283, at P 33 (2009) (noting that the Commission “accord[s] an

appropriate degree of deference to RTO stakeholder processes”); New Eng.

Power Pool, 105 FERC ¶ 61,300, at P 34 (2003) (Commission approval of

transmission cost allocation proposal based upon an extensive and thorough

stakeholder process); Policy Statement Regarding Regional Transmission

Groups, 1991-1996 FERC Stats. & Regs., Regs. Preambles ¶ 30,976, at

30,872 (1993) (the Commission will afford the appropriate degree of

deference to the stakeholder approval process). The Commission’s deference

to RTO stakeholder processes has been upheld by the courts. See Pub. Serv.

Comm’n of Wis. v. FERC, 545 F.3d 1058, 1062-63 (D.C. Cir. 2008) (noting

that the Commission often gives weight to RTO proposals that reflect the

position of the majority of the RTO’s stakeholders) (quoting Am.Elec. Power

Serv. Corp. v. Midwest Indep. Transmission Sys. Operator, Inc., 122 FERC ¶

61, 083, at P 172 (2008)). 24

See 18 C.F.R. § 35.3 at (a)(1).


July 17, 2013

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V. ADDITIONAL INFORMATION

A. Documents Submitted with this Filing:

In addition to this transmittal letter, the following documents are included with this

filing:

Clean and Redline Tariff revisions under the Sixth Revised Volume No. 1

B. Service:

SPP has electronically served a copy of this filing on all its Members and Customers.

A complete copy of this filing will be posted on the SPP web site, www.spp.org, and

is also being served on all affected state commissions.

C. Requisite Agreement:

These revisions to the SPP Tariff do not require any contracts or agreements.

D. Part 35.13 Cost of Service Support

To the extent necessary, SPP requests waiver of any provisions of section 35.13 of the

Commission’s regulations that may be deemed to require cost support in the form of

cost-of-service statements for the enclosed revisions. SPP notes that the enclosed

revisions do not modify applicable Commission-approved rates.

E. Communications

Correspondence and communications with respect to this filing should be sent to, and

SPP requests the Secretary to include on the official service list, the following:

Nicole Wagner

Manager–Regulatory Policy

Southwest Power Pool, Inc.

201 Worthen Drive

Little Rock, AR 72223

Telephone: (501) 688-1642

Fax: (501) 482-2022

[email protected]

Matthew S. Harward

Attorney


201 Worthen Drive


Telephone: (501) 614-3560

Fax: (501) 482-2022

[email protected]

mailto:[email protected]



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VI. CONCLUSION

For all of the foregoing reasons, SPP respectfully requests that the Commission

accept the Tariff revisions proposed herein as just and reasonable, with the effective

date as discussed above.

Respectfully submitted,

/s/ Matthew S. Harward

Matthew S. Harward


201 Worthen Drive


Telephone: (501) 614-3260

[email protected]

Attorney for



American Electric Power - West

Rate Sheet for Point-To-Point Transmission Service

The currently effective rates for Point-To-Point Transmission Service in the American

Electric Power – West (“AEPW”) rate zone are set forth in the “AEP-West PTP Rate Att T” tab

of the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website.

Transmission Owners that have Commission approved rate(s) in the AEPW rate zone are:

American Electric Power (“AEP”); East Texas Electric Cooperative, Inc., Tex-La Electric

Cooperative of Texas, Inc., and Deep East Electric Cooperative, Inc., (hereinafter referred to

collectively as “the Texas Electric Cooperatives”); Oklahoma Municipal Power Authority

(“OMPA”); AEP West Transmission Companies (“AEP-West Transco”) and Coffeyville

Municipal Light and Power (CMLP).


Rates for Point-To-Point Transmission Service specified in this Attachment T shall be

adjusted to reflect any amount reallocated from the Zonal Annual Transmission Revenue

Requirement in accordance with Section IV.A of Attachment J. The rates, including any

applicable reallocation adjustment, shall be set forth in the RRR File posted on the SPP website.

Firm Point-To-Point Transmission Service

The Transmission Customer shall compensate the Transmission Provider each month for

Reserved Capacity at the sum of the applicable charges based upon the rates set forth in the RRR

File, calculated pursuant to the AEP rate formula and protocols (“AEP Formula Rate”) and the

AEP-West Transco rate formula and protocols (“AEP-West Transco Formula Rate”) set forth in

Attachment H, Addendums 4 and 12, respectively, of the Tariff, and as described below:

1. Yearly delivery: the sum of (a) $483.96/MW for the Texas Electric

Cooperatives, (b) $98.16/MW for OMPA, (c) $332.56/MW for CMLP and

(d) the sum of the firm yearly delivery rates set forth in the AEP Formula

Rate and the AEP-West Transco Formula Rate.

2. Monthly delivery: the sum of the AEP, Texas Electric Cooperatives,

OMPA, CMLP, and AEP-West Transco yearly delivery rates divided by

12 months .

3. Weekly delivery: the sum of the AEP, Texas Electric Cooperatives,


52 weeks.

4. Daily delivery:

On-Peak: the sum of the AEP, Texas Electric Cooperatives,

OMPA, CMLP, and AEP-West Transco yearly delivery rates

divided by 260 days.

Off-Peak: the sum of the AEP, Texas Electric Cooperatives,


divided by 365 days .

Non-Firm Point-To-Point Transmission Service

The Transmission Customer shall compensate the Transmission Provider for Non-Firm

Point-To-Point Transmission Service up to the sum of the applicable charges based upon the

rates set forth in the RRR File, calculated pursuant to the AEP Formula Rate and the AEP-West

Transco Formula Rate and as described below:


OMPA, CMLP, and AEP-West Transco firm yearly delivery rates divided

by 12 months.


OMPA, CMLP. and AEP-West Transco firm yearly delivery rates divided

by 52 weeks.

3. Daily delivery:


OMPA, CMLP, and AEP-West Transco firm yearly delivery rates


Off-Peak the sum of the AEP, Texas Electric Cooperatives,



4. Hourly delivery:



divided by 4,160 hours.

Off-Peak: the sum of the AEP, Texas Electric Cooperatives



For the purpose of the rate specified for Daily delivery the Off-Peak Period shall be

Saturdays, Sundays, New Year’s Day, Memorial Day, Independence Day, Labor Day,

Thanksgiving Day, and Christmas Day and the On-Peak Period shall be all days that are not in

the Off-Peak Period.

For the purpose of the rate specified for Hourly delivery On-Peak is all hours between

HE 0700 and HE 2200, inclusive, Central Time Zone, excluding Sundays and holidays.

Holidays shall be as defined by NERC, currently New Year’s Day, Memorial Day, Independence

Day, Labor Day, Thanksgiving Day, and Christmas Day. Off-Peak is all hours not designated as

On-Peak.

Discounts for Certain Through and Out Service Transactions via AEP Pricing Zone:

For the purpose of this Section, the following definitions shall apply:

AEP: American Electric Power, Inc. including its operating company affiliates located in the

SPP region (Public Service Company of Oklahoma and Southwestern Electric Power Company).

AEP Operating Companies' Tariff: The open access transmission service tariff on file with

the Commission under which the AEP Operating Companies offer, among other services,

ERCOT Regional Transmission Service.

ERCOT: The Electric Reliability Council of Texas.

ERCOT Power Supplier: An electric utility that sells electricity for resale into ERCOT and

takes transmission service under Part IV of the AEP Operating Companies' Tariff for such sales.

Load Serving Entity: Any electric utility operating in ERCOT that serves Native Load

Customers within ERCOT.

Native Load Customer: The wholesale and/or retail power customers of TCC and TNC on

whose behalf TCC and TNC, by statute, franchise, regulatory requirement, or contract, have

undertaken an obligation to construct and operate the TCC and TNC systems to meet the reliable

electric needs of such customers or the wholesale and retail power customers of a Load Serving

Entity who, by statute, franchise, regulatory requirement, or contract has undertaken an

obligation to plan, construct and operate the Load Serving Entity's system to meet the reliable

electric needs of such customers. Native Load Customers do not include load served outside of

ERCOT.

Planned Resource: Any generation resource owned, controlled, or purchased by an ERCOT

Power Supplier or Load Serving Entity and designated as a Planned Resource for the purpose of

serving load located in ERCOT.

TCC: AEP Texas Central Company.

TNC: AEP Texas North Company.

Unplanned Resource: Any generation resource owned or purchased by an ERCOT Power

Supplier or Load Serving Entity, used to serve loads within ERCOT and not designated as a

Planned Resource.

Discount Provision: A Load Serving Entity that takes ERCOT Regional Transmission Service

under Part IV of the AEP Operating Companies' Tariff and also takes transmission service under

Part II of this Tariff to import into ERCOT Planned Resources or Unplanned Resources to serve

its Native Load Customers in ERCOT shall have its zonal rates under Schedules 7 and 8 reduced

by 45.27% in instances when AEP is the applicable pricing zone under the SPP Tariff. This

discount applies only to charges under Schedules 7 and 8 of the SPP Tariff.

City Utilities of Springfield, Missouri









Reserved Capacity at the sum of the applicable charges set forth below:

1. Annual Deliveries: $12,129.093 per MW of Reserved Capacity.

2. Monthly delivery: $1,010.758/MW of Reserved Capacity per month.

3. Weekly delivery: $233.252/MW of Reserved Capacity per week.

4. Daily delivery: $46.650/MW of Reserved Capacity per day.



Point-To-Point Transmission Service up to the sum of the applicable charges set forth below:




4. Hourly Deliveries: $2.496 per MW of Reserved Capacity per hour.

The total demand charge in any day, pursuant to a reservation for Hourly delivery, shall

not exceed the on-peak rate specified for Daily delivery multiplied by the highest amount in

kilowatts of Reserved Capacity in any hour during such day. In addition, the total demand

charge in any week, pursuant to a reservation for Hourly or Daily delivery, shall not exceed the

rate specified for Weekly delivery multiplied by the highest amount in kilowatts of Reserved

Capacity in any hour during such week.

The Empire District Electric Company


The currently effective rates for Point-To-Point Transmission Service in The Empire

District Electric Company Zone are set forth in the “Empire PTP Rate Att T” tab of the Revenue

Requirements and Rates File (“RRR File”) posted on the SPP website.


Rates for Point-To-Point Transmission Service specified in this Attachment T shall be adjusted

to reflect any amount reallocated from the Zonal Annual Transmission Revenue Requirement in

accordance with Section IV.A of Attachment J. The rates, including any applicable reallocation

adjustment, shall be set forth in the RRR File posted on the SPP website.Firm Point-To-Point

Transmission Service


Reserved Capacity at the sum of the applicable charges set forth in the RRR File, calculated

pursuant to The Empire District Electric Company formula rate shown in Attachment H,

Addendum 18, and described below:

1. Yearly delivery: one-twelfth of the rate per MW of Reserved Capacity per year.

2. Monthly delivery: rate per MW of Reserved Capacity per month.

3. Weekly Delivery: rate per MW of Reserved Capacity per week.

4. Daily delivery:

On-Peak: rate per MW of Reserved Capacity per day.

Off-Peak: rate per MW of Reserved Capacity per day.

The total demand charge in any week, pursuant to a reservation for Daily delivery, shall

not exceed the rate specified for Weekly delivery multiplied by the highest amount in megawatts

of Reserved Capacity in any day during such week.



Point-To-Point Transmission Service up to the sum of the applicable charges set forth in the

RRR File, calculated pursuant to The Empire District Electric Company formula rate shown in

Attachment H, Addendum 18, and described below:

1. For Monthly delivery: rate per MW of Reserved Capacity per month.

2. For Weekly delivery: rate per MW of Reserved Capacity per week.

3. For Daily delivery:



4. Hourly delivery:

On-Peak: rate per MWh of Reserved Capacity per hour.

Off-Peak: rate per MWh of Reserved Capacity per hour.


not exceed the rate specified for Daily delivery multiplied by the highest amount in megawatts of

Reserved Capacity in any hour during such day. In addition, the total demand charge in any

week, pursuant to a reservation for Hourly or Daily delivery, shall not exceed the rate specified

for Weekly delivery multiplied by the highest amount in megawatts of Reserved Capacity in any

hour during such week.

Grand River Dam Authority


The currently effective rates for Point-To-Point Transmission Service in the Grand River

Dam Authority Zone are set forth in the “GRDA PTP Rate Att T” tab of the Revenue










pursuant to the Grand River Dam Authority formula rate shown in Attachment H, Addendum 13,

and described below:

1. Yearly delivery: one-twelfth of the rate per kW of Reserved Capacity per year.

2. Monthly delivery: rate per kW of Reserved Capacity per month.

3. Weekly Delivery: rate per kW of Reserved Capacity per week.

4. Daily delivery:

On-Peak: rate per kW of Reserved Capacity per day.

Off-Peak: rate per kW of Reserved Capacity per day.


not exceed the rate specified for Weekly delivery multiplied by the highest amount in kilowatts



The Transmission Customer shall compensate the Transmission Provider for Non Firm


RRR File, calculated pursuant to the Grand River Dam Authority formula rate shown in


1. For Monthly delivery: rate per kW of Reserved Capacity per month.

2. For Weekly delivery: rate per kW of Reserved Capacity per week.




4. Hourly delivery:

On-Peak: rate per kWh of Reserved Capacity per hour.

Off-Peak: rate per kWh of Reserved Capacity per hour.


not exceed the rate specified for Daily delivery multiplied by the highest amount in kilowatts of



for Weekly delivery multiplied by the highest amount in kilowatts of Reserved Capacity in any


Kansas City Power & Light Company


The currently effective rates for Point-To-Point Transmission Service in the Kansas City

Power & Light Company Zone are set forth in the “KCPL PTP Rate Att T” tab of the Revenue










pursuant to the Kansas City Power & Light Company formula rate shown in Attachment H,

Addendum 10, Parts 1 and 2, and described below:



3. Weekly delivery: rate per MW of Reserved Capacity per week.

4. Daily on-peak delivery: rate per MW of Reserved Capacity per day.

5. Daily off-peak delivery: rate per MW of Reserved Capacity per day.







RRR File, calculated pursuant to the Kansas City Power & Light Company formula rate shown

in Attachment H, Addendum 10, Parts 1 and 2, and described below:





5. Hourly on-peak delivery: rate per MW of Reserved Capacity per hour.

6. Hourly off-peak delivery: rate per MW of Reserved Capacity per hour.


not exceed the rate specified for Daily on-peak delivery multiplied by the highest amount in

megawatts of Reserved Capacity in any hour during such day. In addition, the total demand


rate specified for Weekly delivery multiplied by the highest amount in megawatts of Reserved


KCP&L Greater Missouri Operations Company


The currently effective rates for Point-To-Point Transmission Service in the KCP&L

Greater Missouri Operations Company Zone are set forth in the “KCPL-GMO PTP Rate Att T”

tab of the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website.









pursuant to the KCP&L Greater Missouri Operations Company formula rate shown in

Attachment H, Addendum 11, Parts 1 and 2, and described below:












RRR File, calculated pursuant to the KCP&L Greater Missouri Operations Company formula

rate shown in Attachment H, Addendum 11, Parts 1 and 2, and described below:








5. Hourly delivery: The rate per MW of Reserved Capacity per hour for on-peak

service and the rate per MW of Reserved Capacity per hour for off-peak service are stated in the

RRR File. The total demand charge in any day, pursuant to a reservation for Hourly delivery,

shall not exceed the rate specified for Daily on-peak delivery multiplied by the highest amount in





Lincoln Electric System


The currently effective rates for Point-To-Point Transmission Service in the Lincoln

Electric System Zone are set forth in the “LES PTP Rate Att T” tab of the Revenue









Firm Point-To-Point Transmission Service up to the sum of the applicable charges set forth in

the RRR File, calculated pursuant to the Lincoln Electric System formula rate shown in


1. Yearly delivery: one-twelfth of the rate per MW of Reserved Capacity per

year.



4. Daily delivery:



On-Peak is all hours between HE 0700 and HE 2200, inclusive, Central Time

Zone, excluding Sundays and holidays. Holidays shall be as defined by NERC, currently New

Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas

Day.

Off-Peak is all hours not designated as On-Peak.

The total demand charged in any week, pursuant to a reservation for Daily delivery, shall





Non-Firm Point-To-Point Transmission Service up to the sum of the applicable charges set forth

in the RRR File, calculated pursuant to the Lincoln Electric System formula rate shown in




3. Daily delivery:


Off-Peak: rate per /MW of Reserved Capacity per day.

4. Hourly delivery:


Off-Peak: rate per MWh of Reserved Capacity per week.

On-Peak is all hours between HE 0700 and HE 2200, inclusive, Central Time Zone

excluding Sundays and holidays. Holidays shall be as defined by NERC, currently New Year's

Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day.








Mid-Kansas Electric Company, LLC


The currently effective rates for Point-To-Point Transmission Service in the Mid-Kansas

Electric Company, LLC (“MKEC”) rate zone are set forth in the “MKEC PTP Rate Att T” tab of

the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website.





adjustment, shall be set forth in the RRR File posted on the SPP website.Firm Point-To-Point

Transmission Service



pursuant to the Mid-Kansas Electric Company, LLC formula rate shown in Attachment H,

Addendum 19, and ITC Great Plains, LLC, formula rate shown in Attachment H, Addendum 9,

and Prairie Wind Transmission, LLC, formula rate shown in Addendum 15 and described below:












RRR File, calculated pursuant to the Mid-Kansas Electric Company, LLC formula rate shown in

Attachment H, Addendum 19, and ITC Great Plains, LLC, formula rate shown in Attachment H,

Addendum 9, and Prairie Wind Transmission, LLC, formula rate shown in Addendum 15, and

described below:













Midwest Energy, Inc.


The currently effective rates for Point-To-Point Transmission Service in the Midwest

Energy, Inc. Zone are set forth in the “Midwest PTP Rate Att T” tab of the Revenue










pursuant to the Midwest Energy, Inc. formula rate shown in Attachment H, Addendum 14, and

described below:



3. Weekly delivery: rate per kW of Reserved Capacity per week.

4. Daily delivery: rate per kW of Reserved Capacity per day.







RRR File, calculated pursuant to the Midwest Energy, Inc. formula rate shown in Attachment H,





4. Hourly delivery: rate per MWh of Reserved Capacity per hour.







Nebraska Public Power District (“NPPD”)


These Point-To-Point charges shall be calculated using the rate formula set forth in

Addendum 7 of Attachment H of the SPP Tariff (“NPPD Formula Rate”). The results of the

formula calculation shall be posted on the SPP website and in an accessible location on the

NPPD website by December 15 of each calendar year and shall be effective on January 1 of the

following year. The results for the Point-To-Point rates described herein shall be specifically set

forth in the “NPPD PTP Rate Att T” tab of the Revenue Requirements and Rates File (“RRR

File”) posted on the SPP website.








Firm Point-To-Point Transmission Service at the sum of the applicable charges set forth in the

RRR File, calculated pursuant to the NPPD Formula Rate shown in Attachment H, Addendum 7,


1. Annual delivery: Shall be the rate for Reserved Capacity per year specified in line

13 of Page 1 of the Formula Rate Template for NPPD set forth in

Addendum 7 of Attachment H of this Tariff.

2. Monthly delivery: Shall be the rate for Reserved Capacity per month specified in line



3. Weekly delivery: Shall be the rate for Reserved Capacity per week specified in line



4. Daily delivery:

On-Peak: Shall be the rate for Reserved Capacity per day specified in line 16

of Page 1 of the Formula Rate Template for NPPD set forth in


Off-Peak: Shall be the rate for Reserved Capacity per day specified in line 17



Service in the opposite direction of the original schedule shall be considered a new and

separate service under this Tariff requiring payment of a separate charge.

On-Peak is all hours between HE 0700 and HE 2200, inclusive, Central Time Zone,

excluding Saturdays, Sundays and holidays. Holidays shall be as defined by NERC, currently

New Year’s Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and

Christmas Day.

Off-Peak is all hours not designated On-Peak.







in the RRR File, calculated pursuant to the NPPD Formula Rate shown in Attachment H,

Addendum 7, and described below. Service in the opposite direction of the original schedule

shall be considered a new and separate service under this Tariff requiring payment of a separate

charge.







3. Daily delivery:







4. Hourly delivery:

On-Peak: Shall be the rate for Reserved Capacity per hour specified in line



Off-Peak: Shall be the rate for Reserved Capacity per hour specified in line






Christmas Day.



not exceed the On-peak rate specified for Daily delivery multiplied by the highest amount in





Capacity designations at the Point(s) of Receipt will be inclusive of losses.

Oklahoma Gas and Electric Company


These Point-To-Point charges shall be calculated using the Existing Zonal Annual

Transmission Revenue Requirement (“Zonal ATRR”) for the Oklahoma Gas and Electric

Company rate zone as specified in Attachment H, Section I, Table 1, Line 7, Column (3), which

is the sum of Existing Zonal ATRRs referenced in Attachment H, Section I, Table 1, Column (3)

as being in the Oklahoma Gas and Electric Company rate zone. As a result of the rate formula

set forth in Attachment H, Addendum 2-A of this Tariff (“OG&E Formula Rate”) and the OG&E

Formula Rate Implementation Protocols set forth in Attachment H, Addendum 2-B of the Tariff,

the Existing Zonal ATRR referenced in Attachment H, Section I, Table 1, Line 7a, Column (3)

shall be posted on the SPP website by September 1 of each calendar year and shall be effective

on January 1 of the following year. The results for the Point-To-Point rates described herein

shall be specifically set forth in the “OGE PTP Rate Att T” tab of the Revenue Requirements and

Rates File (“RRR File”) posted on the SPP website.









pursuant to the OG&E Formula Rate shown in Attachment H, Addendum 2-A and Addendum 2-

B, and described below:

1. Yearly delivery: the Existing Zonal ATRR referenced in Attachment H, Section

I, Table 1, Line 7a, Column (3) divided by the 12-CP divisor identified on page 1, line 5 of the

OG&E Formula Rate $/kW of Reserved Capacity per year plus $0.0752/kW for Oklahoma

Municipal Power Authority.

2. Monthly delivery: the yearly charge divided by 12 for the $/kW of Reserved

Capacity per month plus $0.0063/kW for Oklahoma Municipal Power Authority.

3. Weekly delivery: the yearly charge divided by 52 for the $/kW Reserved

Capacity per week plus $0.0014/kW for Oklahoma Municipal Power Authority.

4. Weekday delivery: the weekly charge divided by 5 for the $/kW of Reserved

Capacity per day plus $0.0003/kW for Oklahoma Municipal Power Authority.

5. Weekend and Holiday delivery: the weekly delivery charge divided by 7 for the

$/kW of Reserved Capacity per day plus $0.0002/kW for Oklahoma Municipal Power Authority.







RRR File, calculated pursuant to the OG&E Formula Rate shown in Attachment H, Addendum

2-A and Addendum 2-B, and described below:

1. Monthly delivery: the yearly delivery charge for Firm Point-to-Point service

specified above divided by 12 for the $/kW of Reserved Capacity per month plus $0.0063/kW

for Oklahoma Municipal Power Authority.

2. Weekly delivery: the yearly delivery charge for Firm Point-to-Point service

specified above divided by 52 for the $/kW of Reserved Capacity per week plus $0.0014/kW for

Oklahoma Municipal Power Authority.

3. Weekday delivery: the weekly delivery charge divided by 5 for the $/kW of

Reserved Capacity per day plus $0.0003/kW for Oklahoma Municipal Power Authority.



5. Hourly delivery: the weekend and holiday delivery charge divided by 24 for the

$/MW of Reserved Capacity per hour plus $0.0086/MWh for Oklahoma Municipal Power

Authority.


not exceed the Weekend and Holiday Delivery rate specified for Weekday delivery multiplied by

the highest amount in kilowatts of Reserved Capacity in any hour during such day. In addition,

the total demand charge in any week, pursuant to a reservation for Hourly or Daily delivery, shall


of Reserved Capacity in any hour during such week.

Omaha Public Power District (“OPPD”)


These Point-To-Point charges shall be calculated using OPPD’s Formula-based Rate

Template as set forth in Addendum 8 of Attachment H of the SPP Tariff (“OPPD Formula

Rate”). The results of the formula calculation shall be posted on the SPP website by July 20 of

each calendar year and shall be effective on August 1 of such year. The results for the Point-To-

Point rates shall be specifically set forth in the “OPPD PTP Rate Att T” tab of the Revenue










pursuant to the OPPD Formula Rate shown in Attachment H, Addendum 8, and described below:

Monthly delivery: The rate as shown on the Formula-based Rate Template for OPPD, page 1,

line 13 ($/kW/Mo).

Weekly delivery: The rate as shown on the Formula-based Rate Template for OPPD, page 1,

line 14 ($/kW/Week).

Daily delivery:

On-Peak The rate as shown on the Formula-based Rate Template for OPPD, page 1,

line 15 ($/kW/Day)

Off-Peak The rate as shown on the Formula-based Rate Template for OPPD, page 1,

line 16 ($/kW/Day)

For the purposes of the Daily delivery charge, the On-Peak days are Monday through

Friday, excluding the NERC defined holidays of New Year’s Day, Memorial Day, Independence

Day, Labor Day, Thanksgiving Day, and Christmas Day, and Off-Peak days are all other days.

The total demand charge in any week, pursuant to a reservation for Daily delivery, shall not

exceed the rate specified for Weekly delivery multiplied by the highest amount in kilowatts of

Reserved Capacity in any day during such week.




RRR File, calculated pursuant to the OPPD Formula Rate shown in Attachment H, Addendum 8,



line 13 ($/kW/Mo).



Daily delivery:


line 17 ($/kW/Day)


line 17a ($/kW/Day)

Hourly delivery


line 18


line 18a



Day, Labor Day, Thanksgiving Day, and Christmas Day, and the Off-Peak days are all other

days. For the purposes of the Hourly delivery charge, On-Peak hours are all hours between HE

0700 and continuing through HE 2200, excluding Saturdays, Sundays, and the NERC defined

holidays of New Year’s Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day,

and Christmas Day, and Off-Peak hours shall be all other hours.

The total demand charge in any week, pursuant to a reservation for Daily or Hourly

delivery shall not exceed the rate specified for Weekly delivery multiplied by the highest amount

in kilowatts of Reserved Capacity in any hour during such week. In addition, the total demand

charge in any day, pursuant to a reservation for Hourly delivery, shall not exceed the rate

specified for Daily delivery multiplied by the highest amount in kilowatts of Reserved Capacity

in any hour during such day.

Southwestern Public Service Company



Attachment O - SPS of the Xcel Energy Operating Companies Joint Open Access Transmission

Tariff (“Xcel Energy OATT”). The results of the formula calculation shall be posted on the SPP

website and in an accessible location on the SPS OASIS website by October 1 of each calendar

year and shall be effective on January 1 of the following calendar year. The results for the Point-

To-Point rates described herein shall be specifically set forth in the “SPS PTP Rate Att T” tab of










the RRR File, calculated pursuant to the Southwestern Public Service Company formula rate and

Tri-County Electric Cooperative, Inc Formula Rate (“Tri-County Formula Rate”) shown in

Attachment H, Addendum 5, and Addendum 17, respectively and described below:

1. Monthly delivery: Shall be the rate specified on line 11 of Page 1 of the Attachment

O - SPS of the Xcel Energy OATT of Reserved Capacity per

month plus the Firm monthly delivery rate set forth in the Tri-

County Formula Rate.

2. Weekly delivery: Shall be the rate specified on line 12 of Page 1 of the Attachment

O – SPS of the Xcel Energy OATT of Reserved Capacity per week

plus the Firm weekly delivery rate set forth in the Tri-County

Formula Rate.

3. Daily delivery

On-Peak: Shall be the rate specified on line 13, column 3 of Page 1 of the

Attachment O – SPS of the Xcel Energy OATT of Reserved

Capacity per day plus the Firm daily delivery rate set forth in the

Tri-County Formula Rate.

Off-Peak: Shall be the rate specified on line 13, column 5 of Page 1 of the







excluding Sundays and holidays. Holidays shall be as defined by NERC, currently New Year’s









in the RRR File, calculated pursuant to the Southwestern Public Service Company formula rate

and Tri-County Formula Rate shown in Attachment H, Addendum 5, and Addendum 17,

respectively and described below. Service in the opposite direction of the original schedule shall

be considered a new and separate service under this Tariff requiring payment of a separate

charge.


O – SPS of the Xcel Energy OATT of Reserved Capacity per

month plus the Non-Firm monthly delivery rate set forth in the Tri-




plus the Non-Firm Weekly delivery rate set forth in the Tri-County

Formula Rate.

3. Daily delivery

On-Peak: Shall be the rate specified on line 13, column 3 of

Page 1 of the Attachment O – SPS of the Xcel Energy OATT of

Reserved Capacity per day plus the Non-Firm daily delivery rate

set forth in the Tri-County Formula Rate.

Off-Peak: Shall be the rate specified on line 13, column 5 of




4. Hourly delivery



Reserved Capacity per hour plus the Non-Firm hourly delivery rate










Sunflower Electric Power Corporation









Reserved Capacity at up to the sum of the applicable charges set forth below:

1. Yearly delivery: $53,220.40/MW of Reserved Capacity per year.


3. Weekly delivery: $1,023.50/MW of Reserved Capacity per week.






The Transmission Customer shall compensate the Transmission provider for Non-Firm






5. Hourly delivery: $6.08/MW of Reserved Capacity per hour.







Westar Energy, Inc. (Kansas Gas & Electric and Westar Energy)


These Point-To-Point charges shall be calculated using information from the rate formula

set forth in Attachment H, Addendum 3 (“Westar Formula Rate”) and in Attachment H,

Addendum 16 (“Kansas Power Pool Formula Rate”) of this Tariff. The results for the Point-To-

Point rates described herein shall be specifically set forth in the “Westar PTP Rate Att T” tab of

the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website









pursuant to the Westar Formula Rate and Kansas Power Pool Formula Rate shown in

Attachment H, Addendum 3, Parts 1 and 2, and Addendum 16 and described below:

1. Yearly delivery charge: the Zonal Annual Transmission Revenue Requirement,

as referenced in Attachment H, Section I, Table 1, Column (3) of the Westar Zone less any

amount reallocated in accordance with Section IV.A of Attachment J, divided by the 12-CP

divisor identified on the Projected Net Revenue Requirements page, line 13 of the Westar

Formula Rate ($/kW/Yr).

2. Monthly delivery charge: the yearly delivery charge divided by 12 months

($/kW/Mo).

3. Weekly delivery charge: the yearly delivery charge divided by 52 weeks

($/kW/Wk).

4. Daily delivery charge: Peak: the weekly delivery charge divided by 5 days

($/kW/Day).

Off Peak: the weekly delivery charge divided by 7 days

($/kW/Day).


not exceed the Peak Rate specified for Weekly delivery multiplied by the highest amount in

kilowatts of Reserved Capacity in any day during such week.



Point-To-Point Transmission Service up to the sum of the applicable charges set forth in the RRR

File, calculated pursuant to the Westar Formula Rate and Kansas Power Pool Formula Rate

shown in Attachment H, Addendum 3, Parts 1 and 2, and Addendum 16 and described below:

1. Monthly delivery charge: the yearly delivery charge for Firm Point-To-Point

service specified divided by 12 months ($/kW/Mo).

2. Weekly delivery charge: the yearly delivery charge for Firm Point-To-Point

service specified divided by 52 weeks ($/kW/Week).


($/kW/Day).

Off Peak: the weekly delivery charge divided by 7 days ($/kW/Day).

4. Hourly delivery charge: Peak: the daily delivery charge divided by 16 hours

($/kW/Hr).

Off Peak: the daily delivery charge divided by 24 hours ($/kW/Hr).







Western Farmers Electric Cooperative










1. Yearly delivery: one-twelfth of the demand charge of $24.72/kW of Reserved

Capacity per year.

2. Monthly delivery: $2.06/kW of Reserved Capacity per month.

3. Weekly delivery: $0.47538/kW of Reserved Capacity per week.

4. Daily delivery: $0.06791/kW of Reserved Capacity per day.

















American Electric Power - West


The currently effective rates for Point-To-Point Transmission Service in the American

Electric Power – West (“AEPW”) rate zone are set forth in the “AEP-West PTP Rate Att T” tab

of the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website.

Transmission Owners that have Commission approved rate(s) in the AEPW rate zone are:

American Electric Power (“AEP”); East Texas Electric Cooperative, Inc., Tex-La Electric

Cooperative of Texas, Inc., and Deep East Electric Cooperative, Inc., (hereinafter referred to

collectively as “the Texas Electric Cooperatives”); Oklahoma Municipal Power Authority

(“OMPA”); AEP West Transmission Companies (“AEP-West Transco”) and Coffeyville

Municipal Light and Power (CMLP).








Reserved Capacity at the sum of the applicable charges based upon the rates set forth in the RRR

File, calculated pursuant to the AEP rate formula and protocols (“AEP Formula Rate”) and the

AEP-West Transco rate formula and protocols (“AEP-West Transco Formula Rate”) set forth in

Attachment H, Addendums 4 and 12, respectively, of the Tariff, and as described below:

1. Yearly delivery: the sum of (a) $483.96/MW for the Texas Electric

Cooperatives, (b) $98.16/MW for OMPA, (c) $332.56/MW for CMLP and

(d) the sum of the firm yearly delivery rates set forth in the AEP Formula

Rate and the AEP-West Transco Formula Rate.



12 months .



52 weeks.

4. Daily delivery:




Off-Peak: the sum of the AEP, Texas Electric Cooperatives,


divided by 365 days .



Point-To-Point Transmission Service up to the sum of the applicable charges based upon the

rates set forth in the RRR File, calculated pursuant to the AEP Formula Rate and the AEP-West

Transco Formula Rate and as described below:


OMPA, CMLP, and AEP-West Transco firm yearly delivery rates divided

by 12 months.


OMPA, CMLP. and AEP-West Transco firm yearly delivery rates divided

by 52 weeks.

3. Daily delivery:




Off-Peak the sum of the AEP, Texas Electric Cooperatives,



4. Hourly delivery:




Off-Peak: the sum of the AEP, Texas Electric Cooperatives



For the purpose of the rate specified for Daily delivery the Off-Peak Period shall be

Saturdays, Sundays, New Year’s Day, Memorial Day, Independence Day, Labor Day,

Thanksgiving Day, and Christmas Day and the On-Peak Period shall be all days that are not in

the Off-Peak Period.

For the purpose of the rate specified for Hourly delivery On-Peak is all hours between

HE 0700 and HE 2200, inclusive, Central Time Zone, excluding Sundays and holidays.

Holidays shall be as defined by NERC, currently New Year’s Day, Memorial Day, Independence

Day, Labor Day, Thanksgiving Day, and Christmas Day. Off-Peak is all hours not designated as

On-Peak.

Discounts for Certain Through and Out Service Transactions via AEP Pricing Zone:

For the purpose of this Section, the following definitions shall apply:

AEP: American Electric Power, Inc. including its operating company affiliates located in the

SPP region (Public Service Company of Oklahoma and Southwestern Electric Power Company).

AEP Operating Companies' Tariff: The open access transmission service tariff on file with

the Commission under which the AEP Operating Companies offer, among other services,

ERCOT Regional Transmission Service.

ERCOT: The Electric Reliability Council of Texas.

ERCOT Power Supplier: An electric utility that sells electricity for resale into ERCOT and

takes transmission service under Part IV of the AEP Operating Companies' Tariff for such sales.

Load Serving Entity: Any electric utility operating in ERCOT that serves Native Load

Customers within ERCOT.

Native Load Customer: The wholesale and/or retail power customers of TCC and TNC on

whose behalf TCC and TNC, by statute, franchise, regulatory requirement, or contract, have

undertaken an obligation to construct and operate the TCC and TNC systems to meet the reliable

electric needs of such customers or the wholesale and retail power customers of a Load Serving

Entity who, by statute, franchise, regulatory requirement, or contract has undertaken an

obligation to plan, construct and operate the Load Serving Entity's system to meet the reliable

electric needs of such customers. Native Load Customers do not include load served outside of

ERCOT.

Planned Resource: Any generation resource owned, controlled, or purchased by an ERCOT

Power Supplier or Load Serving Entity and designated as a Planned Resource for the purpose of

serving load located in ERCOT.

TCC: AEP Texas Central Company.

TNC: AEP Texas North Company.

Unplanned Resource: Any generation resource owned or purchased by an ERCOT Power

Supplier or Load Serving Entity, used to serve loads within ERCOT and not designated as a

Planned Resource.

Discount Provision: A Load Serving Entity that takes ERCOT Regional Transmission Service

under Part IV of the AEP Operating Companies' Tariff and also takes transmission service under

Part II of this Tariff to import into ERCOT Planned Resources or Unplanned Resources to serve

its Native Load Customers in ERCOT shall have its zonal rates under Schedules 7 and 8 reduced

by 45.27% in instances when AEP is the applicable pricing zone under the SPP Tariff. This

discount applies only to charges under Schedules 7 and 8 of the SPP Tariff.

City Utilities of Springfield, Missouri










1. Annual Deliveries: $12,129.093 per MW of Reserved Capacity.










4. Hourly Deliveries: $2.496 per MW of Reserved Capacity per hour.


not exceed the on-peak rate specified for Daily delivery multiplied by the highest amount in

kilowatts of Reserved Capacity in any hour during such day. In addition, the total demand


rate specified for Weekly delivery multiplied by the highest amount in kilowatts of Reserved


The Empire District Electric Company


The currently effective rates for Point-To-Point Transmission Service in The Empire

District Electric Company Zone are set forth in the “Empire PTP Rate Att T” tab of the Revenue










pursuant to The Empire District Electric Company formula rate shown in Attachment H,




3. Weekly Delivery: rate per MW of Reserved Capacity per week.

4. Daily delivery:









RRR File, calculated pursuant to The Empire District Electric Company formula rate shown in


1. For Monthly delivery: rate per MW of Reserved Capacity per month.

2. For Weekly delivery: rate per MW of Reserved Capacity per week.




4. Hourly delivery:


Off-Peak: rate per MWh of Reserved Capacity per hour.


not exceed the rate specified for Daily delivery multiplied by the highest amount in megawatts of



for Weekly delivery multiplied by the highest amount in megawatts of Reserved Capacity in any


Grand River Dam Authority


The currently effective rates for Point-To-Point Transmission Service in the Grand River

Dam Authority Zone are set forth in the “GRDA PTP Rate Att T” tab of the Revenue










pursuant to the Grand River Dam Authority formula rate shown in Attachment H, Addendum 13,




3. Weekly Delivery: rate per kW of Reserved Capacity per week.

4. Daily delivery:







The Transmission Customer shall compensate the Transmission Provider for Non Firm


RRR File, calculated pursuant to the Grand River Dam Authority formula rate shown in


1. For Monthly delivery: rate per kW of Reserved Capacity per month.

2. For Weekly delivery: rate per kW of Reserved Capacity per week.




4. Hourly delivery:

On-Peak: rate per kWh of Reserved Capacity per hour.

Off-Peak: rate per kWh of Reserved Capacity per hour.







Kansas City Power & Light Company


The currently effective rates for Point-To-Point Transmission Service in the Kansas City

Power & Light Company Zone are set forth in the “KCPL PTP Rate Att T” tab of the Revenue










pursuant to the Kansas City Power & Light Company formula rate shown in Attachment H,

Addendum 10, Parts 1 and 2, and described below:












RRR File, calculated pursuant to the Kansas City Power & Light Company formula rate shown

in Attachment H, Addendum 10, Parts 1 and 2, and described below:



KCP&L Greater Missouri Operations Company


The currently effective rates for Point-To-Point Transmission Service in the KCP&L

Greater Missouri Operations Company Zone are set forth in the “KCPL-GMO PTP Rate Att T”

tab of the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website.









pursuant to the KCP&L Greater Missouri Operations Company formula rate shown in

Attachment H, Addendum 11, Parts 1 and 2, and described below:












RRR File, calculated pursuant to the KCP&L Greater Missouri Operations Company formula

rate shown in Attachment H, Addendum 11, Parts 1 and 2, and described below:








5. Hourly delivery: The rate per MW of Reserved Capacity per hour for on-peak

service and the rate per MW of Reserved Capacity per hour for off-peak service are stated in the

RRR File. The total demand charge in any day, pursuant to a reservation for Hourly delivery,

shall not exceed the rate specified for Daily on-peak delivery multiplied by the highest amount in





Lincoln Electric System


The currently effective rates for Point-To-Point Transmission Service in the Lincoln

Electric System Zone are set forth in the “LES PTP Rate Att T” tab of the Revenue










the RRR File, calculated pursuant to the Lincoln Electric System formula rate shown in


1. Yearly delivery: one-twelfth of the rate per MW of Reserved Capacity per

year.



4. Daily delivery:



On-Peak is all hours between HE 0700 and HE 2200, inclusive, Central Time

Zone, excluding Sundays and holidays. Holidays shall be as defined by NERC, currently New

Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas

Day.


The total demand charged in any week, pursuant to a reservation for Daily delivery, shall






in the RRR File, calculated pursuant to the Lincoln Electric System formula rate shown in




3. Daily delivery:


Off-Peak: rate per /MW of Reserved Capacity per day.

4. Hourly delivery:


Off-Peak: rate per MWh of Reserved Capacity per week.

On-Peak is all hours between HE 0700 and HE 2200, inclusive, Central Time Zone

excluding Sundays and holidays. Holidays shall be as defined by NERC, currently New Year's









Mid-Kansas Electric Company, LLC


The currently effective rates for Point-To-Point Transmission Service in the Mid-Kansas

Electric Company, LLC (“MKEC”) rate zone are set forth in the “MKEC PTP Rate Att T” tab of






adjustment, shall be set forth in the RRR File posted on the SPP website.




pursuant to the Mid-Kansas Electric Company, LLC formula rate shown in Attachment H,

Addendum 19, and ITC Great Plains, LLC, formula rate shown in Attachment H, Addendum 9,

and Prairie Wind Transmission, LLC, formula rate shown in Addendum 15 and described below:












RRR File, calculated pursuant to the Mid-Kansas Electric Company, LLC formula rate shown in

Attachment H, Addendum 19, and ITC Great Plains, LLC, formula rate shown in Attachment H,

Addendum 9, and Prairie Wind Transmission, LLC, formula rate shown in Addendum 15, and

described below:

Midwest Energy, Inc.


The currently effective rates for Point-To-Point Transmission Service in the Midwest

Energy, Inc. Zone are set forth in the “Midwest PTP Rate Att T” tab of the Revenue










pursuant to the Midwest Energy, Inc. formula rate shown in Attachment H, Addendum 14, and

described below:











RRR File, calculated pursuant to the Midwest Energy, Inc. formula rate shown in Attachment H,





4. Hourly delivery: rate per MWh of Reserved Capacity per hour.







Nebraska Public Power District (“NPPD”)



Addendum 7 of Attachment H of the SPP Tariff (“NPPD Formula Rate”). The results of the

formula calculation shall be posted on the SPP website and in an accessible location on the

NPPD website by December 15 of each calendar year and shall be effective on January 1 of the

following year. The results for the Point-To-Point rates described herein shall be specifically set

forth in the “NPPD PTP Rate Att T” tab of the Revenue Requirements and Rates File (“RRR

File”) posted on the SPP website.








Firm Point-To-Point Transmission Service at the sum of the applicable charges set forth in the

RRR File, calculated pursuant to the NPPD Formula Rate shown in Attachment H, Addendum 7,


1. Annual delivery: Shall be the rate for Reserved Capacity per year specified in line









4. Daily delivery:












Christmas Day.

Off-Peak is all hours not designated On-Peak.







in the RRR File, calculated pursuant to the NPPD Formula Rate shown in Attachment H,

Addendum 7, and described below. Service in the opposite direction of the original schedule

shall be considered a new and separate service under this Tariff requiring payment of a separate

charge.







3. Daily delivery:







4. Hourly delivery:

On-Peak: Shall be the rate for Reserved Capacity per hour specified in line



Off-Peak: Shall be the rate for Reserved Capacity per hour specified in line






Christmas Day.



not exceed the On-peak rate specified for Daily delivery multiplied by the highest amount in






Oklahoma Gas and Electric Company


These Point-To-Point charges shall be calculated using the Existing Zonal Annual

Transmission Revenue Requirement (“Zonal ATRR”) for the Oklahoma Gas and Electric

Company rate zone as specified in Attachment H, Section I, Table 1, Line 7, Column (3), which

is the sum of Existing Zonal ATRRs referenced in Attachment H, Section I, Table 1, Column (3)

as being in the Oklahoma Gas and Electric Company rate zone. As a result of the rate formula

set forth in Attachment H, Addendum 2-A of this Tariff (“OG&E Formula Rate”) and the OG&E

Formula Rate Implementation Protocols set forth in Attachment H, Addendum 2-B of the Tariff,

the Existing Zonal ATRR referenced in Attachment H, Section I, Table 1, Line 7a, Column (3)

shall be posted on the SPP website by September 1 of each calendar year and shall be effective

on January 1 of the following year. The results for the Point-To-Point rates described herein

shall be specifically set forth in the “OGE PTP Rate Att T” tab of the Revenue Requirements and

Rates File (“RRR File”) posted on the SPP website.









pursuant to the OG&E Formula Rate shown in Attachment H, Addendum 2-A and Addendum 2-

B, and described below:

1. Yearly delivery: the Existing Zonal ATRR referenced in Attachment H, Section

I, Table 1, Line 7a, Column (3) divided by the 12-CP divisor identified on page 1, line 5 of the

OG&E Formula Rate $/kW of Reserved Capacity per year plus $0.0752/kW for Oklahoma

Municipal Power Authority.

2. Monthly delivery: the yearly charge divided by 12 for the $/kW of Reserved

Capacity per month plus $0.0063/kW for Oklahoma Municipal Power Authority.

3. Weekly delivery: the yearly charge divided by 52 for the $/kW Reserved

Capacity per week plus $0.0014/kW for Oklahoma Municipal Power Authority.

4. Weekday delivery: the weekly charge divided by 5 for the $/kW of Reserved

Capacity per day plus $0.0003/kW for Oklahoma Municipal Power Authority.









RRR File, calculated pursuant to the OG&E Formula Rate shown in Attachment H, Addendum

2-A and Addendum 2-B, and described below:

1. Monthly delivery: the yearly delivery charge for Firm Point-to-Point service

specified above divided by 12 for the $/kW of Reserved Capacity per month plus $0.0063/kW

for Oklahoma Municipal Power Authority.

2. Weekly delivery: the yearly delivery charge for Firm Point-to-Point service

specified above divided by 52 for the $/kW of Reserved Capacity per week plus $0.0014/kW for

Oklahoma Municipal Power Authority.

3. Weekday delivery: the weekly delivery charge divided by 5 for the $/kW of

Reserved Capacity per day plus $0.0003/kW for Oklahoma Municipal Power Authority.



5. Hourly delivery: the weekend and holiday delivery charge divided by 24 for the

$/MW of Reserved Capacity per hour plus $0.0086/MWh for Oklahoma Municipal Power

Authority.


not exceed the Weekend and Holiday Delivery rate specified for Weekday delivery multiplied by

the highest amount in kilowatts of Reserved Capacity in any hour during such day. In addition,

the total demand charge in any week, pursuant to a reservation for Hourly or Daily delivery, shall


of Reserved Capacity in any hour during such week.

Omaha Public Power District (“OPPD”)


These Point-To-Point charges shall be calculated using OPPD’s Formula-based Rate

Template as set forth in Addendum 8 of Attachment H of the SPP Tariff (“OPPD Formula

Rate”). The results of the formula calculation shall be posted on the SPP website by July 20 of

each calendar year and shall be effective on August 1 of such year. The results for the Point-To-

Point rates shall be specifically set forth in the “OPPD PTP Rate Att T” tab of the Revenue










pursuant to the OPPD Formula Rate shown in Attachment H, Addendum 8, and described below:


line 13 ($/kW/Mo).



Daily delivery:


line 15 ($/kW/Day)


line 16 ($/kW/Day)



Day, Labor Day, Thanksgiving Day, and Christmas Day, and Off-Peak days are all other days.

The total demand charge in any week, pursuant to a reservation for Daily delivery, shall not

exceed the rate specified for Weekly delivery multiplied by the highest amount in kilowatts of

Reserved Capacity in any day during such week.




RRR File, calculated pursuant to the OPPD Formula Rate shown in Attachment H, Addendum 8,



line 13 ($/kW/Mo).



Daily delivery:


line 17 ($/kW/Day)


line 17a ($/kW/Day)

Hourly delivery


line 18


line 18a



Day, Labor Day, Thanksgiving Day, and Christmas Day, and the Off-Peak days are all other

days. For the purposes of the Hourly delivery charge, On-Peak hours are all hours between HE

0700 and continuing through HE 2200, excluding Saturdays, Sundays, and the NERC defined

holidays of New Year’s Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day,

and Christmas Day, and Off-Peak hours shall be all other hours.

The total demand charge in any week, pursuant to a reservation for Daily or Hourly

delivery shall not exceed the rate specified for Weekly delivery multiplied by the highest amount

in kilowatts of Reserved Capacity in any hour during such week. In addition, the total demand

charge in any day, pursuant to a reservation for Hourly delivery, shall not exceed the rate

specified for Daily delivery multiplied by the highest amount in kilowatts of Reserved Capacity

in any hour during such day.

Southwestern Public Service Company



Attachment O - SPS of the Xcel Energy Operating Companies Joint Open Access Transmission

Tariff (“Xcel Energy OATT”). The results of the formula calculation shall be posted on the SPP

website and in an accessible location on the SPS OASIS website by October 1 of each calendar

year and shall be effective on January 1 of the following calendar year. The results for the Point-

To-Point rates described herein shall be specifically set forth in the “SPS PTP Rate Att T” tab of










the RRR File, calculated pursuant to the Southwestern Public Service Company formula rate and

Tri-County Electric Cooperative, Inc Formula Rate (“Tri-County Formula Rate”) shown in

Attachment H, Addendum 5, and Addendum 17, respectively and described below:


O - SPS of the Xcel Energy OATT of Reserved Capacity per

month plus the Firm monthly delivery rate set forth in the Tri-




plus the Firm weekly delivery rate set forth in the Tri-County

Formula Rate.

3. Daily delivery

On-Peak: Shall be the rate specified on line 13, column 3 of Page 1 of the




Off-Peak: Shall be the rate specified on line 13, column 5 of Page 1 of the
















in the RRR File, calculated pursuant to the Southwestern Public Service Company formula rate

and Tri-County Formula Rate shown in Attachment H, Addendum 5, and Addendum 17,

respectively and described below. Service in the opposite direction of the original schedule shall

be considered a new and separate service under this Tariff requiring payment of a separate

charge.


O – SPS of the Xcel Energy OATT of Reserved Capacity per

month plus the Non-Firm monthly delivery rate set forth in the Tri-




plus the Non-Firm Weekly delivery rate set forth in the Tri-County

Formula Rate.

3. Daily delivery









4. Hourly delivery













Sunflower Electric Power Corporation









Reserved Capacity at up to the sum of the applicable charges set forth below:









The Transmission Customer shall compensate the Transmission provider for Non-Firm













Westar Energy, Inc. (Kansas Gas & Electric and Westar Energy)


These Point-To-Point charges shall be calculated using information from the rate formula

set forth in Attachment H, Addendum 3 (“Westar Formula Rate”) and in Attachment H,

Addendum 16 (“Kansas Power Pool Formula Rate”) of this Tariff. The results for the Point-To-

Point rates described herein shall be specifically set forth in the “Westar PTP Rate Att T” tab of

the Revenue Requirements and Rates File (“RRR File”) posted on the SPP website









pursuant to the Westar Formula Rate and Kansas Power Pool Formula Rate shown in

Attachment H, Addendum 3, Parts 1 and 2, and Addendum 16 and described below:

1. Yearly delivery charge: the Zonal Annual Transmission Revenue Requirement,

as referenced in Attachment H, Section I, Table 1, Column (3) of the Westar Zone less any

amount reallocated in accordance with Section IV.A of Attachment J, divided by the 12-CP

divisor identified on the Projected Net Revenue Requirements page, line 13 of the Westar

Formula Rate ($/kW/Yr).

2. Monthly delivery charge: the yearly delivery charge divided by 12 months

($/kW/Mo).

3. Weekly delivery charge: the yearly delivery charge divided by 52 weeks

($/kW/Wk).


($/kW/Day).

Off Peak: the weekly delivery charge divided by 7 days

($/kW/Day).


not exceed the Peak Rate specified for Weekly delivery multiplied by the highest amount in

kilowatts of Reserved Capacity in any day during such week.



Point-To-Point Transmission Service up to the sum of the applicable charges set forth in the RRR

File, calculated pursuant to the Westar Formula Rate and Kansas Power Pool Formula Rate

shown in Attachment H, Addendum 3, Parts 1 and 2, and Addendum 16 and described below:

1. Monthly delivery charge: the yearly delivery charge for Firm Point-To-Point

service specified divided by 12 months ($/kW/Mo).

2. Weekly delivery charge: the yearly delivery charge for Firm Point-To-Point

service specified divided by 52 weeks ($/kW/Week).


($/kW/Day).

Off Peak: the weekly delivery charge divided by 7 days ($/kW/Day).

4. Hourly delivery charge: Peak: the daily delivery charge divided by 16 hours

($/kW/Hr).

Off Peak: the daily delivery charge divided by 24 hours ($/kW/Hr).







Western Farmers Electric Cooperative










1. Yearly delivery: one-twelfth of the demand charge of $24.72/kW of Reserved

Capacity per year.


















