secretary federal energy regulatory commission 888 first ... rate...2011/09/28 · transmission...

September 28, 2011

The Honorable Kimberly D. BoseSecretaryFederal Energy Regulatory Commission888 First Street NEWashington, DC 20426

Re: Southwest Power Pool, Inc., Docket No. ER11-____________ Submission of Annual Formula Rate Updates

Honorable Secretary Bose:

Pursuant to section 205 of the Federal Power Act (“FPA”), 16 U.S.C. § 824d, and section 35.13 of the Federal Energy Regulatory Commission’s (“Commission” or “FERC”) regulations, 18 C.F.R. § 35.13, Southwest Power Pool, Inc. (“SPP”) submits revisions to its Open Access Transmission Tariff (“Tariff”) to implement annual updates for Public Service Company of Oklahoma (“PSO”), Southwestern Electric Power Company (“SWEPCO”), AEP Southwestern Transmission Company, Inc., and AEP Oklahoma Transmission Company, Inc. (collectively the “AEP West Transmission Companies”). The revisions track the rate update calculated on behalf of PSO, SWEPCO, and the AEP West Transmission Companies (collectively, the “AEP Companies”), based on the AEP Companies’ transmission cost of service formula rates in the Tariff. Pursuant to the annual formula rate update protocols in the Tariff, this filing also alters the Zonal Annual Transmission Revenue Requirement (“ATRR”) for the AEP West zone within SPP, the Base Plan Region-wide ATRR, and the Base Plan Zonal ATRR in Attachment H of the Tariff, as well as the Base Plan Zonal Rate for Point-To-Point Transmission Service and the Region-wide Rate for Point-To-Point Transmission Service in Schedule 11 of the Tariff.1 SPP requests an effective date of July 1, 2011 for the Tariff revisions submitted in this filing.

1 All capitalized terms, if not defined in this transmittal letter, shall have the

meaning set forth in the Tariff.

The Honorable Kimberly D. BoseSeptember 28, 2011Page 2

I. Background

A. Description of SPP and Tariff Transmission Rates

As a Regional Transmission Organization (“RTO”), SPP administers the provision of open access transmission service on a regional basis across the facilities of the SPP transmission owners.2 The Tariff specifies zonal rates for transmission service. For service to load located within the SPP region, the transmission rates are based on the ATRR for the host zone within which the load is located.3 For service to load located outside of the SPP region, the transmission charge is based on the lowest cost zone interconnected with the control area external to the SPP region that is the designated point of delivery, i.e., the interface between SPP and the receiving system.4 The ATRR for each pricing zone is set out in Attachment H of the Tariff. The rates for Point-To-Point Transmission Service, based on the ATRR in Attachment H, are set forth in Attachment T of the Tariff. The transmission owner controls the filing of rate changes for its zone. SPP, in turn, as administrator of the Tariff, makes the filings necessary to incorporate any such rate changes into the Tariff.5

In accordance with specific criteria detailed in Section III.A of Attachment J of the Tariff, SPP allocates the costs of Base Plan Upgrades6 to the Base Plan Region-wide ATRR to be recovered through the Region-wide Charge7 and/or to the Base Plan Zonal ATRR to be recovered through the Base Plan Zonal Charge. For example, if a transmission upgrade for which a Notification to Construct (“NTC”) was issued prior to June 19, 2010, qualifies as a Base Plan Upgrade, and the cost of such upgrade exceeds $100,000, one-third of the cost of the upgrade is allocated to the entire SPP region in the form of a Base Plan Region-wide ATRR in Table 2 of Attachment H of the Tariff.8 The

2 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 (1998).

3 See Tariff at Schedules 7-9.

4 See id.

5 See Westar Energy, Inc., 122 FERC ¶ 61,268, at P 105 (2008) (requiring SPP to include each transmission owner’s rate formula in the Tariff).

6 See Tariff at Attachment J, Section III.A. In order to qualify as a Base Plan Upgrade, transmission facilities must satisfy specific criteria (detailed in Section III.B of Attachment J) or receive a waiver of such criteria from SPP (the conditions for which are specified in Section III.C of Attachment J).

7 See id. at Attachment J, Section III.A.2.i.

8 See id.


Base Plan Region-wide ATRR then is recovered through the Region-wide Charge for Network Integration Transmission Service and the Base Plan Region-wide Point-To-Point Transmission Service charges in accordance with Schedule 11 of the Tariff. The remaining two-thirds of the cost of the Base Plan Upgrade is allocated to the various SPP zones (based on each zone’s incremental positive MW-mile benefits from the Base Plan Upgrade) in the Base Plan Zonal ATRR in Column 4 of Table 1 of Attachment H of the Tariff. The Base Plan Zonal ATRR then is recovered through the Base Plan Zonal Charge for Network Integration Transmission Service and Base Plan Zonal charges for Point-To-Point Transmission Service according to Schedule 11 of the Tariff.9

For a Base Plan Upgrade for which an NTC was issued after June 19, 2010, and the nominal operating voltage level is greater than or equal to 300 kV, 100 percent of the costs of the upgrade will be allocated to the Base Plan Region-wide ATRR and recovered through the Region-wide Charge. The Region-wide Charge will be recovered for Network Integration Transmission Service and Region-wide Point-To-Point Transmission Service according to Schedule 11.

B. Description of the AEP Companies and Associated Formula Rates

American Electric Power Service Corporation (“AEP”) is a multi-state electric utility holding company system whose operating companies provide electric service at wholesale and retail in parts of eleven states. PSO and SWEPCO are AEP operating companies providing service in Oklahoma, Louisiana, Arkansas, and Texas. PSO and SWEPCO are also transmission-owning members of SPP. AEP has implemented a transmission cost of service formula rate for transmission services over PSO’s and SWEPCO’s facilities,10 which is incorporated into the Tariff.11 AEP’s formula rate includes a true-up mechanism implemented at the end of each rate year, with the new charges taking effect on July 1 each year.12 SPP filed, and the Commission accepted,

9 See Tariff at Attachment J, Section III.A.2.ii. If the cost of the Base Plan Upgrade

is less than or equal to $100,000, the ATRR associated with the Base Plan Upgrade is allocated to the Base Plan Zonal ATRR of the zone in which the Base Plan Upgrade is located. See id. at Attachment J, Section III.A.1.

10 See Am. Elec. Power Serv. Corp., 127 FERC ¶ 61,292 (2009) (accepting PSO and SWEPCO formula rate settlement agreement).

11 See Tariff at Attachment H, Addendum 4. See also Sw. Power Pool, Inc., Letter Order, Docket No. ER08-1549-000 (Nov. 10, 2008) (accepting incorporation of PSO and SWEPCO formula rate into Tariff).

12 See id. at Attachment H, Addendum 4, Section I.2 (the charges resulting from each annual update for PSO and SWEPCO will become effective on July 1 of each year).


PSO and SWEPCO’s annual formula rate update filing for year 2010, effective July 1, 2010, in Docket No. ER11-2194-000.13

The AEP West Transmission Companies are transmission owning public utility subsidiaries of the AEP Transmission Company, LLC (“AEPTCo”). AEP established AEPTCo to develop, construct, own, and operate transmission facilities interconnected to existing AEP operating companies’ facilities within the SPP RTO region. The AEP West Transmission Companies are transmission-owning members of SPP. The AEP West Transmission Companies’ formula rate is incorporated into the Tariff.14 SPP filed, and the Commission accepted, the AEP West Transmission Companies’ annual formula rate update filing for year 2010, effective July 1, 2010, in Docket No. ER11-2198-000.15

II. Description of Filing

SPP submits this filing to incorporate into the Tariff the updated charges for transmission service applicable to the AEP Companies’ within the AEP West pricing zone. Consistent with the formula rates and protocols for the AEP Companies in the Tariff, the AEP Companies provide SPP with data to input into the AEP Companies’ formula rates in the Tariff. The source of the data is the AEP Companies’ FERC Form 1 for the year 2010. The updated data results in changes to the ATRRs for Network Integration Service and Point-To-Point Rates for the AEP West pricing zones. Accordingly, SPP submits updates to Attachments H and T of the Tariff, which reflect the updated ATRR for Point-To-Point Rates and Network Integration Transmission Service charges applicable to the AEP West pricing zone. The updated data also results in changes to the revenue requirements for the allocation of through and out transaction revenue. Therefore, in this filing, SPP submits Tariff revisions incorporating these changes in Addendum 1 to Schedule 1 (Revenue Requirements for the Allocation of Through and Out Transaction Revenue).

In addition, certain of the AEP Companies added facilities to their rate base through the annual update process that qualify for Base Plan funding. As discussed above, pursuant to Attachment J of the Tariff the costs of such facilities are partially allocated throughout the SPP region.16 Therefore, the addition of Base Plan funded 13 See Sw. Power Pool, Inc., Letter Order, Docket Nos. ER11-2194-000 and ER11-

2198-000 (Jan. 13, 2011) (“January Letter Order”).

14 See Tariff at Attachment H, Addendum 12.

15 See January Letter Order.

16 See Tariff at Attachment J, Section III.A. In order to qualify as a Base Plan Upgrade, transmission facilities must satisfy specific criteria (detailed in Section III.B of Attachment J) or receive a waiver of such criteria from SPP (the conditions for which are specified in Section III.C of Attachment J).


facilities resulted in changes to the AEP Companies’ Base Plan Zonal and Region-wide ATRRs; and therefore, the Region-wide and Base Plan Zonal Point-To-Point service Addendum 1 and 2 to Schedule 11 also must be revised. These revisions are consistent with Attachment J of the Tariff with respect to the Base Plan Zonal and Region-wide charges, discussed supra.

To illustrate the updated rates in this filing, SPP also includes in this filing: (a) a spreadsheet specifying the Base Plan Upgrades and credits, as well as the revenue requirement amounts and the region-wide and zonal allocation of the costs, and the calculation of the revised Base Plan Zonal and Base Plan Region-wide Point-to-Point Transmission Service charges, supporting the revisions effective July1, 2011, as Exhibit No. 1.

III. Effective Date and Request for Waiver

SPP respectfully requests that the Commission accept the submitted revisions effective July 1, 2011. Therefore, pursuant to section 35.11 of the Commission’s rules and regulations, 18 C.F.R. § 35.11, SPP requests a waiver of the Commission’s 60-day notice requirement set forth at 18 C.F.R. § 35.3. Waiver is appropriate because this would allow the updated charges for service to the AEP West zone within SPP to become effective on the same day as they became effective under the AEP Companies’ formula rates.17

IV. Additional Information

A. Information Required by Section 35.13 of the Commission’s Regulations, 18 C.F.R. § 35.13:18

1. Documents enclosed:

In addition to this transmittal letter, the following items are included: (a) clean and redline Tariff revisions under the Sixth Revised Volume No. 1; (b) a spreadsheet, described above, supporting the revisions effective July 1, 2011, as Exhibit No. 1.

17 See supra note 12; January Letter Order.

18 Because SPP is merely seeking to implement annual updates pursuant to a Commission-approved formula rate for the AEP Companies, SPP is not submitting any cost of service information. As SPP serves only a ministerial function here; it is AEP that bears the responsibility for justifying its rates.


2. Effective date:

As discussed above, SPP requests an effective date of July 1, 2011 for the submitted Tariff changes. SPP requests a waiver of the Commission’s 60-day notice requirement set forth at 18 C.F.R. § 35.3 to allow this effective date.

3. Names and addresses of persons to whom this filing has been mailed:

A copy of this filing has been served on all SPP Members and Customers, as well as on affected state regulatory commissions. In addition, a copy of this filing will be posted on the SPP web page (www.spp.org).

4. Description of filing:

A description of changes, along with the reasons for these changes, is provided above.

5. Requisite agreements:

None required.

6. Costs alleged or judged illegal, duplicative, or unnecessary.

None.

7. Basis of rates, etc.:

The basis of the rates and charges proposed in this filing is explained above and in the attached materials.

8. Specifically assignable facilities installed or modified:

There are none.


B. Correspondence and 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:

Heather H. Starnes, J.D.Manager – Regulatory PolicySouthwest Power Pool, Inc.415 North McKinley, Suite 140,Plaza WestLittle Rock, AR 72205Telephone: (501) 614-3380Fax: (501) [email protected]

Carrie L. BumgarnerTyler R. BrownWright & Talisman, P.C.1200 G Street, NW, Suite 600Washington, D.C. 20005Telephone: (202) 393-1200Fax: (202) [email protected]@wrightlaw.com

V. Conclusion

For the reasons stated herein, SPP requests that the Commission accept SPP’s proposed revisions to its Tariff effective July 1, 2011.

Respectfully submitted,

/s/Tyler R. Brown______Tyler R. Brown

K:\SPP\AEP rate update letter.doc

Exhibit No. 1

Southwest Power Pool, Inc.

Calculation of Base Plan ATRR Amounts - Region And By Zone

Each Project's Revenue

Region-Wide Revenue

Requirement

Total Zonal Revenue

Requirement to be allocated to

zones AEP West Springfield Empire GRDA KCPL OG+E Midwest KCPL-GMO SPA SPS Sunflower WFEC Westar

Mid Kansas Electric Coop LES OPPD NPPD

Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone ZoneBase Plan projects with NTCs issued prior to June 19, 2010Westar Energy, Inc. Base Plan Funded ProjectsLine - Cities Service - 3rd & Van Buren 69kV ~ $1,315,605 (3) $434,150 $881,455 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $881,455 $0 $0 $0 $0Line - Circle - Hutchinson Energy Center 115kV ~ $0 (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Multi- HEC - 43rd & Lorraine - Tower 33 69kV ~ $0 (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Multi - Hutchinson 115kV Conversion ~ $0 (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Multi - Morris - McDowell 230 kV $955,419 (3) $315,288 $640,131 $0 $0 $0 $0 $34,132 $0 $0 $0 $0 $0 $15,515 $0 $571,735 $18,749 $0 $0 $0

Transformer - Butler 138/69kV $260,124 (3) $85,841 $174,283 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $174,283 $0 $0 $0 $0Line - Chisholm - Grant 69kV Ckt 1 $110,094 (3) $36,331 $73,763 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $73,763 $0 $0 $0 $0Line - HTI Junction - Circleville 115kV $511,405 (3) $168,764 $342,641 $19,646 $0 $0 $0 $17,364 $14,810 $0 $0 $0 $26,840 $0 $0 $190,275 $73,706 $0 $0 $0Line - Hesston-Golden Plain - Gatz 69kV $283,969 (3) $93,710 $190,259 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $190,259 $0 $0 $0 $0Line - Jarbalo-166th St-Jaggard Jct-Pentagon 115kV $456,387 (3) $150,608 $305,779 $0 $0 $0 $0 $33,011 $0 $0 $4,971 $0 $4,911 $0 $0 $262,886 $0 $0 $0 $0Line - Stranger Creek - Thornton Street 115kV $1,373,569 (3) $453,278 $920,291 $0 $0 $0 $0 $123,624 $0 $0 $0 $0 $0 $0 $0 $796,667 $0 $0 $0 $0Line - Dearing - Coffeyville - CRA 69kV $193,224 (3) $63,764 $129,460 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $129,460 $0 $0 $0 $0Line - Ft Junction - Anzio 115kV $806,126 (3) $266,022 $540,104 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $540,104 $0 $0 $0 $0Line - Murray Gill EC East - Murray Gill Jct 69kV $364,878 (3) $120,410 $244,468 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $244,468 $0 $0 $0 $0Line - West McPherson - Wheatland $540,367 (3) $178,321 $362,046 $0 $0 $0 $0 $14,482 $0 $0 $0 $0 $0 $0 $0 $347,564 $0 $0 $0 $0Line - McDowell Creek - Ft Junction 115kV $1,173,338 (3) $387,202 $786,136 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $786,136 $0 $0 $0 $0Device - UDALL 2 69kV Capacitor $60,408 (3) $19,935 $40,473 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $40,473 $0 $0 $0 $0Device - Parsons 69kV $51,086 (3) $16,858 $34,228 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $34,228 $0 $0 $0 $0Device - Clearwater 138kV $77,733 (3) $25,652 $52,081 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $52,081 $0 $0 $0 $0Device - NE Parsons 138kV $112,171 (3) $37,016 $75,155 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $75,155 $0 $0 $0 $0XFR - County Line 115/69kV $510,673 (3) $168,522 $342,151 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $342,151 $0 $0 $0 $0Li M Gill EDLine - Murray Gill ED - MacArthur 69kV $21,449 (3) $7,078 $14,371 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $14,371 $0 $0 $0 $0Device - 3rd & VanBuren 115kV $58,218 (3) $19,212 $39,006 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $39,006 $0 $0 $0 $0Device - Sunset 69 kV Capacitor $237,550 (3) $78,392 $159,158 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $159,158 $0 $0 $0 $0XFR - Stranger Creek 345/115 #2 Addition $1,546,234 (3) $510,257 $1,035,977 $20,011 $0 $0 $0 $219,107 $20,761 $29,205 $0 $0 $0 $25,741 $0 $721,151 $0 $0 $0 $0Line - Knob Hill - Steele City 115 kV $4,920,004 (3) $1,623,601 $3,296,403 $113,311 $0 $0 $0 $143,450 $100,404 $29,361 $193,804 $0 $31,168 $232,309 $0 $1,226,255 $329,343 $0 $0 $896,997Line - Kelly - Seneca 115kV $795,349 (3) $262,465 $532,884 $0 $0 $0 $0 $0 $0 $0 $28,923 $0 $0 $0 $0 $503,961 $0 $0 $0 $0Line - TEC - Midland $0 (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Line - Summit - NE Saline 115kV $1,273,912 (3) $420,391 $853,521 $0 $0 $0 $0 $0 $0 $53,365 $0 $0 $0 $21,308 $0 $735,735 $43,114 $0 $0 $0Line - Coffeyville - Dearing 115kV $469,651 (3) $154,985 $314,666 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $314,666 $0 $0 $0 $0Mutli - NW Manhattan $209,174 (3) $69,027 $140,147 $812 $0 $0 $0 $1,281 $706 $0 $687 $0 $1,197 $919 $0 $116,664 $16,897 $0 $0 $982Line - Timber Jct - Winfield 69 kV $1,156,842 (3) $381,758 $775,084 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $775,084 $0 $0 $0 $0

Device - Nortonville 69kV Cap $182,632 (3) $60,269 $122,363 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $122,363 $0 $0 $0 $0Line - 27th & Croco - Tecumseh hill 115 kV $650,772 (3) $214,755 $436,017 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $436,017 $0 $0 $0 $0Line - Gill EC - Peck 69 kV Rebuild $1,152,572 (3) $380,349 $772,223 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $772,223 $0 $0 $0 $0Line - Coffeyville - Dearing 138kV $0 (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Line - Weaver - Rose Hill $353,683 (3) $116,715 $236,968 $32,757 $0 $0 $0 $0 $34,742 $0 $0 $0 $0 $0 $0 $169,469 $0 $0 $0 $0Line - Circle - HEC GT 115 kV Rebuild $101,944 (3) $33,641 $68,303 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $68,303 $0 $0 $0 $0Line: Jarbalo-Stranger Ckt 2 (Tap Line) NWLeavenworth $206,558 (3) $68,164 $138,394 $1,774 $0 $0 $0 $23,860 $0 $0 $2,420 $0 $0 $0 $0 $107,143 $0 $0 $0 $3,197

Line: Gill - Clearwater 138 kV $751,789 (3) $248,090 $503,699 $0 $0 $0 $0 $0 $15,728 $0 $0 $0 $0 $0 $0 $464,450 $23,521 $0 $0 $0Line: Richland - Rosehill Jct 69 kV $90,291 (3) $29,796 $60,495 $5,601 $0 $0 $0 $0 $7,936 $0 $0 $0 $0 $0 $0 $46,957 $0 $0 $0 $0Line: Chisolm-Ripley 69 kV (Rebuild) $180,256 (3) $59,484 $120,772 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $120,772 $0 $0 $0 $0Line: Stranger-NW Leav (Tap Line) $505,271 (3) $166,740 $338,531 $4,341 $0 $0 $0 $58,365 $0 $0 $5,919 $0 $0 $0 $0 $262,087 $0 $0 $0 $7,820Line: 27th & Croco-41st & Calif 115 kV $363,301 (3) $119,889 $243,412 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $243,412 $0 $0 $0 $0Line: Vernon-Athens 69 kV $370,686 (3) $122,326 $248,360 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $248,360 $0 $0 $0 $0Line: Athens-Owl Crk (600 Rd) 69 kV $175,705 (3) $57,983 $117,722 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $117,722 $0 $0 $0 $0Line: Owl Creek-Lehigh Tap 69 kV $66,285 (3) $21,874 $44,411 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $44,411 $0 $0 $0 $0

BP Rev Req Allocation and PTP Rates AEP_Transcos_ 7-1-2011.xls Page 1 of 33 Rev. Req. Allocation




Region-Wide Revenue

Requirement

Total Zonal Revenue




Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone ZoneLine: Sumner Co-Timber Jct 138 kV $648,916 (3) $214,142 $434,774 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $434,774 $0 $0 $0 $0Device: Timber Jct 138 kV Capacitor $143,150 (3) $47,240 $95,910 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $95,910 $0 $0 $0 $0

Device: Tioga 69 kV Capacitor $59,914 (3) $19,772 $40,142 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $40,142 $0 $0 $0 $0~The amounts associated with these projects have been input in the first project as a sum amount.

AEP - West Base Plan Funded ProjectsCache-Snyder to Altus Jct. 138 kV line (w/2 ring bus stations) -PSO 2,582,254 (3) $852,144 $1,730,110 $1,730,110 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Catoosa 138 kV Device (Cap. Bank)-PSO 65,738 (3) $21,694 $44,044 $44,044 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Dyess to S. Fayetteville 69 kV Convert to 161 kV (multi-projects)-SWEPCO 2,471,504 (3) $815,596 $1,655,908 $511,887 $40,145 $38,452 $136,162 $63,350 $604,446 $0 $20,241 $0 $27,381 $0 $95,307 $93,769 $24,766 $0 $0 $0Linwood McWillie 138kV-SWEPCO 347,838 (3) $114,787 $233,051 $233,051 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Northwest Texarkana-Bann-Alumax Tap 138kV -- reconductor-SWEPCO 718,810 (3) $237,207 $481,603 $481,603 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Tontitown - Elm Springs REC 161 kV line***-SWEPCO - (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Siloam Springs - Chamber Springs 161 kV line***-SWEPCO - (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Carthage REC - Carthage T 138 kV -SWEPCO 664,466 (3) $219,274 $445,192 $445,192 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Arsenal Hill 138kV Device-SWEPCO 90,678 (3) $29,924 $60,754 $60,754 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Riverside-Glenpool (81-523)Reconductor-PSO 161,531 (3) $53,305 $108,226 $108,226 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Craig Jct. to Broken Bow Dam 138 Rebuild (7.7mi)-PSO 861,931 (3) $284,437 $577,494 $554,421 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $23,072 $0 $0 $0 $0 $0

WFEC New 138 kV Ties: Sayre to Erick (WFEC) Line & Atoka and Tupelo station work-PSO 2,218,151 (3) $731,990 $1,486,161 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,486,161 $0 $0 $0 $0 $0Pryor Junction 138/69 Upgrade Transf-PSO 268,936 (3) $88,749 $180,187 $103,901 $0 $15,660 $60,626 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Elk City - Elk City 69 kV line (CT Upgrades)*-PSO 14,059 (1) $0 $14,059 $14,059 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Weleetka & Okmulgee Wavetrap replacement 81-805*-PSO 9,191 (1) $0 $9,191 $9,191 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Tulsa Southeast Upgrade (repl switches)*-PSO 12,095 (1) $0 $12,095 $12,095 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Wavetrap Clinton City-Foss Tap 69kV Ckt 1-PSO 2,025 (3) $668 $1,357 $1,357 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Arsenal Hill Auto xfmr & AH to Water Works line-SWEPCO 3,274,902 (3) $1,080,718 $2,194,184 $2,194,184 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0SW Shreveport (sub work & tap)-SWEPCO 1,617,335 (3) $533,721 $1,083,614 $1,083,614 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0[NW Ark Area Improve - 2009] E. Centerton-Flint Crk, E Rogers-N Rogers, Centerton-SWEPCO 2,276,279 (3) $751,172 $1,525,107 $1,451,498 $0 $0 $27,778 $0 $45,831 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Rebuild N. Magazine - Danville 161 kV Line-SWEPCO 2,124,969 (3) $701,240 $1,423,729 $1,293,311 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $130,418 $0 $0 $0 $0 $0

[Greenwood, AR Area Improve] N Huntington, Greenwood, Reeves, Bonanza-SWEPCO 551,046 (3) $181,845 $369,201 $369,201 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Port Robson-Caplis Line (SW 138 kV Loop -- 2009) -SWEPCO 4,857,819 (3) $1,603,080 $3,254,739 $3,254,739 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Linwood 138 Station Switch Replacement* - SWEPCO 13,060 (1) $0 $13,060 $13,060 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0





Region-Wide Revenue

Requirement

Total Zonal Revenue




Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone

Knox Lee - Oak Hill #2 138 kV line, S. Shreveport (SWE Minor Proj II)-SWEPCO 46,304 (3) $15,280 $31,024 $31,024 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0NW Henderson - Oak Hill 138 kV line*-SWEPCO 20,094 (3) $0 $20,094 $20,094 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Wallace Lake-Prt Robson-Red Point 138 kV Loop-SWEPCO 793,826 (3) $261,962 $531,864 $531,864 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

[NW Ark Area Improve - 2008] Elm Springs, East Rogers, Shipe Road Stations-SWEPCO (12,405) (3) ($4,094) ($8,311) ($8,311) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Daingerfield - Jenkins REC 69 kV CB Repl -SWEPCO 91,246 (3) $30,111 $61,135 $61,135 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Port Robson (SW 138 kV Loop -- 2008) SWEPCO - (3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Reconductor 4 mi. of McNabb-Turk-SWEPCO (2,572) (3) ($849) ($1,723) ($1,723) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Longwood: r&r switches, upgrade bus-SWEPCO (342/138/13.2kv xfr ckt1) 25,321 (3) $8,356 $16,965 $16,965 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Reconductor: Greggton-Lake Lamond & Quitman-Westwood 69 kV lines-SWEPCO 437,886 (3) $144,502 $293,384 $293,384 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Rebuild/reconductor Dyess-Elm Springs REC [Dyess Station-Flint Creek] SWEPCO 445,400 (3) $146,982 $298,418 $298,418 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Replace switch at Diana*-SWEPCO 8,040 (1) $0 $8,040 $8,040 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Whitney repl CB and Switches* SWEPCO 13,154 (1) $0 $13,154 $13,154 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Bartlesville SE to N Bartlesville Rebuild PSO 172,343 (3) $56,873 $115,470 $55,908 $0 $0 $0 $0 $16,589 $0 $0 $0 $0 $0 $0 $42,973 $0 $0 $0 $0Coffeyville Tap to N Bartlesville Rebuild PSO 79,253 (3) $26,153 $53,100 $22,116 $0 $0 $2,536 $1,918 $5,697 $0 $0 $0 $0 $0 $0 $20,833 $0 $0 $0 $0

AEP Transco Base Plan Funded ProjectsSnyder 138kV Terminal Addition - OKT 111,383 (3) $36,756 $74,627 $74,627 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Coffeyville T to Dearing 138kV Rebuild 1.1 mi - OKT 160,694 (3) $53,029 $107,665 $107,665 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Tulsa Power Station Reactor 138kV - OKT see belowBartlesville SE to N Bartlesville Rebuild -OKT 1,088,259 (3) $359,125 $729,134 $353,028 $0 $0 $0 $0 $104,753 $0 $0 $0 $0 $0 $0 $271,352 $0 $0 $0 $0Coffeyville Tap to N Bartlesville Rebuild - OKT 500,440 (3) $165,145 $335,295 $139,649 $0 $0 $16,015 $12,109 $35,975 $0 $0 $0 $0 $0 $0 $131,547 $0 $0 $0 $0*




Region-Wide Revenue

Requirement

Total Zonal Revenue




Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone ZoneCedar Lane-Canadian 138kV Line - replace 800A wave trap to allow 1200A limit* $6,679 (1) $0 $6,679 $0 $0 $0 $0 $0 $6,679 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Bodle Substation - Install 138kV breaker, associated line relaying & communications $137,847 (3) $45,490 $92,357 $0 $0 $0 $0 $0 $92,357 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Ardmore-Rocky Point 69kV Line - rebuild & reconductor 0.82 miles of line with 477AS33 $51,107 (3) $16,865 $34,242 $0 $0 $0 $0 $0 $34,242 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Tiger Creek Substation - install 69kV, 9 MVAR capacitor bank $46,341 (3) $15,293 $31,048 $0 $0 $0 $0 $0 $31,048 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0Sooner - Rose Hill 345 kV Line (CWIP) $3,856,326 (3) $1,272,587 $2,583,739 $340,423 $10,700 $29,368 $48,320 $16,625 $865,882 $0 $26,522 $0 $84,999 $48,389 $18,855 $1,052,245 $41,409 $0 $0 $0Sunnyside - Hugo 345 kV Line (CWIP) $10,940,841 (3) $3,610,478 $7,330,363 $3,444,438 $0 $0 $33,335 $35,488 $2,154,814 $0 $31,259 $0 $354,799 $43,140 $747,119 $397,868 $16,887 $0 $0 $71,216

SPS/Xcel Base Plan Funded ProjectsBailey County 115/69kV Transformer 320,241$ (3) $105,679 $214,562 $0 $0 $0 $0 $0 $0 $0 $0 $0 $214,562 $0 $0 $0 $0 $0 $0 $0Mustand Station N 230/115kV Transformer 277,833$ (3) $91,685 $186,148 $0 $0 $0 $0 $0 $0 $0 $0 $0 $186,148 $0 $0 $0 $0 $0 $0 $0Denver City 115/69kV Transformer 340,623$ (3) $112,406 $228,217 $0 $0 $0 $0 $0 $0 $0 $0 $0 $228,217 $0 $0 $0 $0 $0 $0 $0Hockley County Interchange: Transformer Upgrade 260,089$ (3) $85,829 $174,260 $0 $0 $0 $0 $0 $0 $0 $0 $0 $174,260 $0 $0 $0 $0 $0 $0 $0Terry County Interchange: Transformer Upgrade 288,081$ (3) $95,067 $193,014 $0 $0 $0 $0 $0 $0 $0 $0 $0 $193,014 $0 $0 $0 $0 $0 $0 $0Roswell Interchange 115kV - 69 kV Transformer 99,626$ (3) $32,876 $66,750 $6,838 $0 $0 $0 $0 $0 $0 $0 $0 $52,653 $0 $7,259 $0 $0 $0 $0 $0Seven Rivers - Pecos - Potash 230kV 2,000,820$ (3) $660,271 $1,340,549 $9,244 $0 $0 $0 $0 $0 $0 $0 $0 $1,331,304 $0 $0 $0 $0 $0 $0 $0Yoakum County Interchange 230/115kV Transformer 193,803$ (3) $63,955 $129,848 $4,928 $0 $0 $0 $0 $0 $0 $0 $0 $124,920 $0 $0 $0 $0 $0 $0 $0

Seminole - Hobbs 230kV 2,429,054$ (3) $801,588 $1,627,466 $10,762 $0 $0 $0 $0 $10,143 $0 $0 $0 $1,606,561 $0 $0 $0 $0 $0 $0 $0Nichols 230/115kV Transformer 889 074$ (3) $293 394 $595 680 $34 915 $0 $0 $0 $0 $10 999 $0 $0 $0 $549 767 $0 $0 $0 $0 $0 $0 $0Transformer 889,074$ (3) $293,394 $595,680 $34,915 $0 $0 $0 $0 $10,999 $0 $0 $0 $549,767 $0 $0 $0 $0 $0 $0 $0Lubbock East 115/69kV Transformer 348,270$ (3) $114,929 $233,341 $0 $0 $0 $0 $0 $0 $0 $0 $0 $233,341 $0 $0 $0 $0 $0 $0 $0Hale County 115/69kV Transformer 179,944$ (3) $59,381 $120,563 $16,019 $0 $0 $0 $0 $16,973 $0 $0 $0 $82,415 $0 $0 $5,156 $0 $0 $0 $0Cochran 115/69kV Transformer 223,660$ (3) $73,808 $149,852 $0 $0 $0 $0 $0 $0 $0 $0 $0 $149,852 $0 $0 $0 $0 $0 $0 $0Curry County - North Clovis Conversion 22,102$ (3) $7,294 $14,808 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $14,808 $0 $0 $0 $0 $0

OPPD Base Plan Funded ProjectsOPPD Sub 1255/3422 Transformer Project 1,534,328$ (4) $506,328 $1,028,000 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,028,000 $0Sub 1305 and 161 Transm. Expan. Project 624,147$ (3) $205,969 $418,178 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $418,178 $0

NPPD Base Plan Funded ProjectsXFR - Grand Island auto 3 818,569$ (3) $270,128 $548,441 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $20,292 $528,149Line - Jeffrey - Gothenburg 115 kV line 12,374$ (3) $4,083 $8,291 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $8,291Line - NPPD - Steele City - Kansas Border 115 kV 182,948$ (3) $60,373 $122,575 $4,413 $0 $0 $0 $5,638 $0 $0 $7,600 $0 $0 $9,071 $0 $47,927 $12,870 $0 $0 $35,056Multi - North Platte 230/115 kV Transformers 683,814$ (3) $225,659 $458,155 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $458,155

ETR Project Phase 1 2,205,922$ (4) $727,954 $1,477,968 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,477,968Multi - ETR Project 13,953,163$ (3) $4,604,544 $9,348,619 $65,440 $0 $0 $0 $46,743 $37,394 $28,046 $9,349 $0 $65,440 $121,532 $9,349 $84,138 $0 $84,138 $514,174 $8,282,876Bloomfield Wind Generation Interconnection $392,328 (3) $129,468 $262,860 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $262,860South Sioux City 115/69 kV Sub $337,421 (3) $111,349 $226,072 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $226,072Spalding-Albion, Refurb L1192B $167,440 (3) $55,255 $112,185 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $112,185Line-LoupCity-North Loup, Refurb L1168 $202,047 (3) $66,676 $135,371 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $135,371Petersburg 115kV 15 MVAR Cap. Bank $51,488 (3) $16,991 $34,497 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $34,497Ainsworth 115kV Sub. Exp. Cap Bank* $5,316 (1) $0 $5,316 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $5,316





Region-Wide Revenue

Requirement

Total Zonal Revenue




Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone ZoneValentine 115 kV Capacitor Bank $47,437 (3) $15,654 $31,783 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $31,783Gordon 115 kV 9 MVAR Cap Bank Add. $50,496 (3) $16,664 $33,832 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $33,832Kearney 115 kV 36 MVAR Cap Bank Addition $8,352 (3) $2,756 $5,596 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $5,596*




Region-Wide Revenue

Requirement

Total Zonal Revenue




Facility Description Requirement Notes Amount Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone

Totals with NTCs issued before June 19, 2010 $106,447,197 $35,079,386 $71,367,811 $20,240,744 $50,845 $83,480 $324,772 $2,929,144 $5,930,740 $139,977 $873,269 $0 $5,756,588 $517,924 $2,613,815 $16,622,239 $601,262 $84,138 $1,980,644 $12,618,219

Base Plan Funded Credits

Revenue Requirements

Westar Energy - Reservation 1293991 $10,388 (2,3) $3,428 $6,960 $0 $0 $0 $0 $3,703 $400 $0 $0 $0 $685 $0 $0 $2,172 $0 $0 $0 $0

Totals $10,388 $3,428 $6,960 $0 $0 $0 $0 $3,703 $400 $0 $0 $0 $685 $0 $0 $2,172 $0 $0 $0 $0

Region-Wide ATRR Att. H Table 2 Line 1 (NTCs issued

PRIOR to 6/10/2010) $35,082,814 $71,374,771 $20,240,744 $50,845 $83,480 $324,772 $2,932,847 $5,931,140 $139,977 $873,269 $0 $5,757,273 $517,924 $2,613,815 $16,624,411 $601,262 $84,138 $1,980,644 $12,618,219

Balance Portfolio projects & Base Plan projects with NTCs issued after June 19, 2010AEP Transco Base Plan Funded ProjectsTulsa Power Station Reactor 138kV - OKT 125,485 (11) $41,410 $84,075 $84,075 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Zonal H/B Revenues $84,075 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Projects with CWIP in Rate Base

ITC Great Plains

KETA $9,547,887 (5) $9,547,887 Bal. PortV Plan 418,413$ (10) $418,413 PP-H/B

OG&E Woodward District EHV - Hitchland 345kV Line (Priority Project - CWIP) $333,330 (10) $333,330 PP-H/BWoodward District EHV - Comanche County 345 kV Line y(Priority Project - CWIP) $36,239 (10) $36,239 PP-H/B

Sooner - Cleveland 345 kV Line (Balance Portfolio - CWIP) $1,170,701 (5) $1,170,701 Bal. PortWoodward District EHV - Tuco 345 kV Line (Balance Portfolio - CWIP) $97,924 (5) $97,924 Bal. PortSeminole - Muskogee 345 kV Line (Balance Portfolio - CWIP) $444,916 (5) $444,916 Bal. Port

Prairie Wind Transmission, LLC

Medicine Lodge to Woodward & Medicine Lodge to MKEC & WR's Wichita Substation (Priority Project - CWIP) $2,565,561 (10) $2,565,561 PP-H/B

Balanced Portfolio Region-wide ATRR Total for Att. H

Table 2 Line 4 11,261,429$

H/B Region-wide Totals for Att H. Table 2 Line 2 $3,394,953

H/B ZonalTotals $84,075 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Grand Total ATRR for Att. H Table 1 Col 4 Zonal $71,374,771 $20,240,744 $50,845 $83,480 $324,772 $2,932,847 $5,931,140 $139,977 $873,269 $0 $5,757,273 $517,924 $2,613,815 $16,624,411 $601,262 $84,138 $1,980,644 $12,618,219

don’t use

Grand Total ATRR for Att. H Table 1 Col 5 Zonal $84,075 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0

Grand Total ATRR for Region-wide & Zonal

Schedule 11 PTP rates $49,739,196 $20,324,819 $50,845 $83,480 $324,772 $2,932,847 $5,931,140 $139,977 $873,269 $0 $5,757,273 $517,924 $2,613,815 $16,624,411 $601,262 $84,138 $1,980,644 $12,618,219




Zonal Allocation Factors

AEP West Cleco Springfield Empire GRDA KCPL OG+E Midwest KCPL-GMO SPA SPS Sunflower WFEC Westar

Mid Kansas Electric Coop LES OPPD NPPD Check

Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone TotalFacility Description

Westar Energy, Inc. Base Plan Funded ProjectsLine - Cities Service - 3rd & Van Buren 69kV ~ 100.00000% 0.00000% 100.00000%Line - Circle - Hutchinson Energy Center 115kV ~ 100.00000% 0.00000% 100.00000%Multi- HEC - 43rd & Lorraine - Tower 33 69kV ~ 100.00000% 0.00000% 100.00000%Multi - Hutchinson 115kV Conversion ~ 100.00000% 100.00000%Multi - Morris - McDowell 230 kV 5.33203% 2.42372% 89.31538% 2.92887% 100.00000%

Transformer - Butler 138/69kV 100.00000% 0.00000% 100.00000%Line - Chisholm - Grant 69kV Ckt 1 100.00000% 100.00000%Line - HTI Junction - Circleville 115kV 5.73373% 5.06774% 4.32223% 7.83328% 55.53177% 21.51125% 100.00000%Line - Hesston-Golden Plain - Gatz 69kV 100.00000% 0.00000% 100.00000%

Line - Jarbalo-166th St-Jaggard Jct-Pentagon 115kV 10.79577% 1.62554% 1.60622% 85.97248% 100.00000%Line - Stranger Creek - Thornton Street 115kV 13.4% 86.56683% 100.00000%Line - Dearing - Coffeyville - CRA 69kV 100.00000% 100.00000%Line - Ft Junction - Anzio 115kV 100.00000% 100.00000%Line - Murray Gill EC East - Murray Gill Jct 69kV 100.00000% 100.00000%Line - West McPherson - Wheatland 4.00000% 96.00000% 100.00000%Line - McDowell Creek - Ft Junction 115kV 100.00000% 100.00000%Device - UDALL 2 69kV Capacitor 100.00000% 100.00000%Device - Parsons 69kV 100.00000% 100.00000%Device - Clearwater 138kV 100.00000% 100.00000%Device - NE Parsons 138kV 100.00000% 100.00000%

XFR - County Line 115/69kV 100.00000% 100.00000%Li M Gill EDLine - Murray Gill ED - MacArthur 69kV 100.00000% 100.00000%Device - 3rd & VanBuren 115kV 100.00000% 100.00000%Device - Sunset 69 kV Capacitor 100.00000% 100.00000%XFR - Stranger Creek 345/115 #2 Addition 1.93164% 21.14978% 2.00401% 2.81910% 2.48474% 69.61074% 100.00000%Line - Knob Hill - Steele City 115 kV 3.44% 4.35% 3.05% 0.89% 5.88% 0.95% 7.05% 37.20% 9.99% 27.21% 100.00000%

Line - Kelly - Seneca 115kV 5.43% 94.57% 100.00000%Line - TEC - Midland 15.01438% 84.98562% 100.00000%Line - Summit - NE Saline 115kV 6.25228% 2.49643% 86.19997% 5.05133% 100.00000%Line - Coffeyville - Dearing 115kV 100.00% 100.00000%Mutli - NW Manhattan 0.58% 0.91% 0.50% 0.49% 0.85% 0.66% 83.24% 12.06% 0.70% 100.00000%Line - Timber Jct - Winfield 69 kV 100.00% 100.00000%

Device - Nortonville 69kV Cap 100.00000% 100.00000%Line - 27th & Croco - Tecumseh hill 115 kV 100.00% 100.00000%Line - Gill EC - Peck 69 kV Rebuild 100.00% 100.00000%Line - Coffeyville - Dearing 138kV 0.00000%Line - Weaver - Rose Hill 13.82337% 14.66102% 71.51561% 100.00000%Line - Circle - HEC GT 115 kV Rebuild 100.00000% 100.00000%

Line: Jarbalo-Stranger Ckt 2 (Tap Line) NWLeavenworth 1.28% 17.24% 1.75% 77.42% 2.31% 100.00000%

Line: Gill - Clearwater 138 kV 3.1224958% 92.20782% 4.6697% 100.00000%Line: Richland - Rosehill Jct 69 kV 9.26% 13.12% 77.62% 100.00000%Line: Chisolm-Ripley 69 kV (Rebuild) 100.00% 100.00000%Line: Stranger-NW Leav (Tap Line) 1.28% 17.24% 1.75% 77.42% 2.31% 100.00000%Line: 27th & Croco-41st & Calif 115 kV 100.00% 100.00000%Line: Vernon-Athens 69 kV 100.00% 100.00000%Line: Athens-Owl Crk (600 Rd) 69 kV 100.00% 100.00000%Line: Owl Creek-Lehigh Tap 69 kV 100.00% 100.00000%Line: Sumner Co-Timber Jct 138 kV 100.00% 100.00000%Device: Timber Jct 138 kV Capacitor 100.00% 100.00000%

Page 7 of 33






Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone TotalDevice: Tioga 69 kV Capacitor 100.00% 100.00000%

AEP - West Base Plan Funded ProjectsCache-Snyder to Altus Jct. 138 kV line (w/2 ring bus stations) -PSO 100.00000% 100.00000%Catoosa 138 kV Device (Cap. Bank)-PSO 100.00000% 100.00000%Dyess to S. Fayetteville 69 kV Convert to 161 kV (multi-projects)-SWEPCO 30.91279% 2.42438% 2.32213% 8.22279% 3.82572% 36.50239% 1.22237% 1.65353% 5.75558% 5.66271% 1.49562% 100.00000%Linwood McWillie 138kV-SWEPCO 100.00000% 100.00000%Northwest Texarkana-Bann-Alumax Tap 138kV -- reconductor-SWEPCO 100.00000% 100.00000%

Tontitown - Elm Springs REC 161 kV line***-SWEPCO 100.00000% 100.00000%Siloam Springs - Chamber Springs 161 kV line***-SWEPCO 12.11564% 3.19654% 10.59195% 45.60134% 21.07250% 2.51377% 4.90827% 100.00000%Carthage REC - Carthage T 138 kV -SWEPCO 100.00000% 100.00000%Arsenal Hill 138kV Device-SWEPCO 100.00000% 100.00000%Riverside-Glenpool (81-523)Reconductor-PSO 100.00% 100.00000%

Craig Jct. to Broken Bow Dam 138 Rebuild (7.7mi)-PSO 96.00% 4.00% 100.00000%WFEC New 138 kV Ties: Sayre to Erick (WFEC) Line & Atoka and Tupelo station work-PSO 100.00% 100.00000%Pryor Junction 138/69 Upgrade Transf-PSO 57.66% 8.69% 33.65% 100.00000%Elk City - Elk City 69 kV line (CT Upgrades)*-PSO 100.00% 100.00000%Weleetka & Okmulgee W t l t 81Wavetrap replacement 81-805*-PSO 100.00% 100.00000%Tulsa Southeast Upgrade (repl switches)*-PSO 100.00000% 100.00000%Wavetrap Clinton City-Foss Tap 69kV Ckt 1-PSO 100.00000%

Arsenal Hill Auto xfmr & AH to Water Works line-SWEPCO 100.00% 100.00000%SW Shreveport (sub work & tap)-SWEPCO 100.00% 100.00000%[NW Ark Area Improve - 2009] E. Centerton-Flint Crk, E Rogers-N Rogers, Centerton-SWEPCO 95.17% 1.82% 3.01% 100.00000%Rebuild N. Magazine - Danville 161 kV Line-SWEPCO 90.84% 9.16% 100.00000%[Greenwood, AR Area Improve] N Huntington, Greenwood, Reeves, Bonanza-SWEPCO 100.00% 100.00000%Port Robson-Caplis Line (SW 138 kV Loop -- 2009) -SWEPCO 100.00% 100.00000%Linwood 138 Station Switch Replacement* - SWEPCO 100.00% 100.00000%

Knox Lee - Oak Hill #2 138 kV line, S. Shreveport (SWE Minor Proj II)-SWEPCO 100.00% 100.00000%NW Henderson - Oak Hill 138 kV line*-SWEPCO 100.00% 100.00000%

Wallace Lake-Prt Robson-Red Point 138 kV Loop-SWEPCO 100.00% 100.00000%[NW Ark Area Improve - 2008] Elm Springs, East Rogers, Shipe Road Stations-SWEPCO 100.00% 100.00000%Daingerfield - Jenkins REC 69 kV CB Repl -SWEPCO 100.00% 100.00000%Port Robson (SW 138 kV Loop -- 2008) SWEPCO 100.00% 100.00000%Reconductor 4 mi. of McNabb-Turk-SWEPCO 100.00% 100.00000%Longwood: r&r switches, upgrade bus-SWEPCO (342/138/13.2kv xfr ckt1) 100.00% 100.00000%

Reconductor: Greggton-Lake Lamond & Quitman-Westwood 69 kV lines-SWEPCO 100.00% 100.00000%

Page 8 of 33






Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Total

Rebuild/reconductor Dyess-Elm Springs REC [Dyess Station-Flint Creek] SWEPCO 100.00% 100.00000%Replace switch at Diana*-SWEPCO 100.00% 100.00000%Whitney repl CB and Switches* SWEPCO 100.00% 100.00000%Bartlesville SE to N Bartlesville Rebuild PSO 48.4175% 14.3668% 37.2157% 100.00000%Coffeyville Tap to N Bartlesville Rebuild PSO 41.6495% 4.7764% 3.6116% 10.7294% 39.2331% 100.00000%

AEP Transco Base Plan Funded ProjectsSnyder 138kV Terminal Addition - OKT 100.00% 100.00000%

Coffeyville T to Dearing 138kV Rebuild 1.1 mi - OKT 100.00% 100.00000%Bartlesville SE to N Bartlesville Rebuild -OKT 48.4175% 14.3668% 37.2157% 100.00000%Coffeyville Tap to N Bartlesville Rebuild - OKT 41.6495% 4.7764% 3.6116% 10.7294% 39.2331% 100.00000%*






Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone Zone TotalSeven Rivers - Pecos - Potash 230kV 0.69% 99.31% 100.00000%

Yoakum County Interchange 230/115kV Transformer 3.80% 96.20% 100.00000%

Seminole - Hobbs 230kV 0.66% 0.62% 98.72% 100.00000%Nichols 230/115kV Transformer 5.86% 1.85% 92.29% 100.00000%Lubbock East 115/69kV Transformer 100.00000% 100.00000%Hale County 115/69kV Transformer 13.29% 14.08% 68.36% 4.28% 100.00000%Cochran 115/69kV Transformer 100.00% 100.00000%Curry County - North Clovis Conversion 100.00000% 100.00000%

OPPD Base Plan Funded ProjectsOPPD Sub 1255/3422 Transformer Project 100.00000% 100.00000%Sub 1305 and 161 Transm. Expan. Project 100.00000% 100.00000%

NPPD Base Plan Funded ProjectsXFR - Grand Island auto 3 3.70000% 96.30000% 100.00000%Line - Jeffrey - Gothenburg 115 kV line 100.00000% 100.00000%Line - NPPD - Steele City - Kansas Border 115 kV 3.60000% 4.60000% 6.20000% 7.40000% 39.10000% 10.50000% 28.60000% 100.00000%Multi - North Platte 230/115 kV Transformers 100.00000% 100.00000%

ETR Project Phase 1 100.00000%Multi - ETR Project 0.70000% 0.50000% 0.40000% 0.30000% 0.10000% 0.70000% 1.30000% 0.10000% 0.90000% 0.90000% 5.50000% 88.60000% 100.00000%Bloomfield Wind Generation Interconnection 100.00000% 100.00000%South Sioux City 115/69 kV S b 100 00000% 100 00000%Sub 100.00000% 100.00000%Spalding-Albion, Refurb L1192B 100.00000% 100.00000%Line-LoupCity-North Loup, Refurb L1168 100.00000% 100.00000%Petersburg 115kV 15 MVAR Cap. Bank 100.00000% 100.00000%Ainsworth 115kV Sub. Exp. Cap Bank* 100.00000% 100.00000%Valentine 115 kV Capacitor Bank 100.00000% 100.00000%Gordon 115 kV 9 MVAR Cap Bank Add. 100.00000% 100.00000%Kearney 115 kV 36 MVAR Cap Bank Addition 100.00000% 100.00000%*


Calculation of Base Plan ATRR Amounts - Region

And By Zone

(1)

The Region-Wide Revenue Requirement Amount for each project or reservation is 0%, pursuant to the provisions of Tariff Attachment J because the investment is less than $100,000. The remainder of the Revenue Requirement is the Zonal Revenue Requirement Amount.

(2) Westar Energy - Reservation 1293991 has an impact on the LaCygne - West Gardner Economic Upgrade. The revenue requirement that is base plan funded is twelve times the monthly levelized cost of this use of the upgrade. Such monthly levelized cost is determined by calculating the load proportionate share of the total annual revenue requirement of the upgrade for each year of the reservation period and levelizing such costs.

(3) The Region-Wide Revenue Requirement Amount for each project or reservation is equal to the product of the Revenue Requirement shown and 33% pursuant to the provisions of Tariff

Notes

product of the Revenue Requirement shown and 33%, pursuant to the provisions of Tariff Attachment J. The remainder of the Revenue Requirement is the Zonal Revenue Requirement Amount for NTCs prior to June 19, 2010

(4) The Region-Wide Revenue Requirement Amount for each project or reservation is equal to the product of the Revenue Requirement shown and 33%, pursuant to the provisions of Tariff Attachment J. The remainder of the Revenue Requirement is the Zonal Revenue Requirement Amount pursuant to provisions of Tariff Section I. Common Service Provisions, Base Plan Upgrades Definition. The upgrade will be allocated 1/3 to the region and the remaining 2/3s will be allocated 100% to the zone with the applicable MW-Mile benefit allocation for NTC's prior to June 19, 2010.

(5) One hundred percent (100%) of the Annual Transmission Revenue Requirement for an approvedBalanced Portfolio shall be recovered through the Region-wide Charge.

(10) For all Base Plan Upgrades with NTCs on or after June 19, 2010, whose nominal operatingvoltage level is greater than or equal to 300 kV, the Region-Wide Revenue Requirement Amountfor each project or reservation is 100% of the Revenue Requirement shown pursuant to theprovisions of Tariff Attachment J. (Also referred to as Highway/Byway)

(11) For all Base Plan Upgrades with NTCs on or after June 19, 2010, whose nominal operatingvoltage level is less than 300 kV but greater than 100 kV, the Region-Wide Revenue RequirementAmount for each project or reservation is equal 33% of the Revenue Requirement shownpursuant to the provisions of Tariff Attachment J. The remainder of the Revenue Requirement isthe Zonal Revenue Requirement Amount pursuant to provisions of Tariff Section I. CommonService Provisions, Base Plan Upgrades Definition. The upgrade will be allocated 1/3 to theregion and the remaining 2/3s will be allocated 100% to the zone. (Also referred to asHighway/Byway)

(12) For all Base Plan Upgrades with NTCs on or after June 19, 2010, whose nominal operatingvoltage level is less than or equal to 100 kV, the Region-Wide Revenue Requirement Amount foreach project or reservation is 0% of the Revenue Requirement shown pursuant to the provisionsof Tariff Attachment J. The remainder of the Revenue Requirement is the Zonal RevenueRequirement Amount pursuant to provisions of Tariff Section I. Common Service Provisions,Base Plan Upgrades Definition. The upgrade will be allocated 100% to the zone. (Also referred toas Highway/Byway)

Description Amount Notes

Base Plan Region Wide ATRR $49,739,196 BPRATRR

12 CP Average Transmission System Load (MW) 34,884 MTRL

Firm Point-To-Point Transmission Service

Annual Rate / MW $1,425.8569 BPRRMonthly Rate / MW $118.8214 Annual Rate / 12Weekly Rate / MW $27.4203 Annual Rate / 52


Calculation of Base Plan Point-To-Point RatesRegion Wide Point-To-Point Rate

On Peak Day Rate / MW $5.4841 Weekly Rate / 5Off Peak Day Rate / MW $3.9172 Weekly Rate / 7

Non-Firm Point-To-Point Transmission Service

Monthly Rate / MW $118.8214 Annual Rate / 12Weekly Rate / MW $27.4203 Annual Rate / 52

On Peak Day Rate / MW $5.4841 Monthly Rate x 12 / 260Off Peak Day Rate / MW $3.9065 Monthly Rate x 12 / 365

On Peak Hourly Rate / MW $0.3428 Monthly Rate x 12 / 4160Off Peak Hourly Rate / MW $0.1628 Monthly Rate x 12 / 8760


Base Plan Zonal ATRR $20,324,819 BPZATRR

12 CP Average Transmission System Load (MW) 8,008 MZTL


Annual Rate / MW $2,538.1010 BPZRMonthly Rate / MW $211.5084 Annual Rate / 12Weekly Rate / MW $48 8096 Annual Rate / 52


Calculation of Base Plan Point-To-Point RatesZonal Point-To-Point Rate

AEP - West Zone

Weekly Rate / MW $48.8096 Annual Rate / 52On Peak Day Rate / MW $9.7619 Weekly Rate / 5Off Peak Day Rate / MW $6.9728 Weekly Rate / 7






Base Plan Zonal ATRR $50,845 BPZATRR

12 CP Average Transmission System Load (MW) 550 MZTL


Annual Rate / MW $92.4735 BPZRMonthly Rate / MW $7.7061 Annual Rate / 12Weekly Rate / MW $1.7783 Annual Rate / 52



City Utilities of Springfield, Missouri Zone





On Peak Hourly Rate / MW $0.0222 Monthly Rate x 12 / 4160

Off Peak Hourly Rate / MW $0.0106 Monthly Rate x 12 / 8760








Empire District Electric Company Zone

y $On Peak Day Rate / MW $0.3374 Weekly Rate / 5Off Peak Day Rate / MW $0.2410 Weekly Rate / 7












Grand River Dam Authority Zone













Kansas City Power & Light Company Zone













Oklahoma Gas & Electric Company Zone













Midwest Energy, Inc Zone

y $On Peak Day Rate / MW $1.9108 Weekly Rate / 5Off Peak Day Rate / MW $1.3649 Weekly Rate / 7









Annual Rate / MW $571.7294 BPZRMonthly Rate / MW $47.6441 Annual Rate / 12

$10 9948



KCP&L Greater Missouri Operations Company Zone













Southwestern Public Service Zone













Sunflower Electric Corporation Zone













Western Farmers Electric Cooperative Zone













Westar Energy, Inc. Zone













Mid Kansas Electric Company Zone










Annual Rate / MW $114.4345 BPZRMonthly Rate / MW $9.5362 Annual Rate / 12Weekly Rate / MW $2 2007 Annual Rate / 52



Lincoln Electric System













Omaha Public Power District













Nebraska Public Power District






Southwest Power Pool, Inc.Regional and Zonal Transmission System Peak Loads (MW)Calendar Year 2010

Zone January February March April May June July August September October November December Total AverageCSWS(AEP) 8,552.89 7,396.73 6,937.94 5,949.15 8,194.37 9,744.70 9,629.10 10,402.05 8,994.21 6,512.58 6,388.29 7,392.60 96,094.61 8,007.88

EDE 1,204.00 1,017.00 883.00 628.00 870.00 1,097.00 1,089.00 1,161.14 976.08 669.05 807.08 1,018.11 11,419.46 951.62

GMO 1,682.00 1,491.00 1,240.00 1,066.00 1,549.00 1,853.00 1,886.00 1,995.00 1,628.00 1,135.00 1,317.00 1,487.00 18,329.00 1,527.42

GRDA 729.00 666.00 607.00 553.00 711.00 813.00 813.00 884.00 766.00 576.00 582.00 654.00 8,354.00 696.17

KCPL 3,013.40 2,634.40 2,297.40 2,197.40 3,029.40 3,625.40 3,642.39 3,840.40 3,159.40 2,271.40 2,407.40 2,631.40 34,749.79 2,895.82

LES 743.00 669.00 621.00 599.00 745.00 851.00 920.00 931.00 748.00 653.00 655.00 688.00 8,823.00 735.25

MKEC 467.00 432.00 408.00 402.00 479.00 630.00 643.00 672.00 563.00 450.00 430.00 431.00 6,007.00 500.58

MIDW 248.00 234.00 223.00 221.00 264.00 359.00 381.00 391.00 314.00 261.00 240.00 245.00 3,381.00 281.75

NPPD 2,402.70 2,295.64 2,039.01 1,791.51 2,011.12 2,277.58 2,689.92 2,853.05 2,122.82 1,749.11 2,083.30 2,179.77 26,495.54 2,207.96

OKGE 5,012.009 4,523.073 4,078.611 3,746.195 5,174.381 6,230.482 6,320.312 6,757.449 5,899.898 4,177.297 4,013.222 4,366.282 60,299.21 5,024.93

OPPD 1 810 72 1 636 18 1 475 90 1 417 94 1 956 18 2 181 08 2 358 77 2 421 58 1 808 02 1 555 13 1 623 03 1 668 33 21 912 84 1 826 07

Monthly Peak Load (MW) 2010

OPPD 1,810.72 1,636.18 1,475.90 1,417.94 1,956.18 2,181.08 2,358.77 2,421.58 1,808.02 1,555.13 1,623.03 1,668.33 21,912.84 1,826.07

SECI 326.00 381.00 306.00 308.00 384.00 480.00 504.00 505.00 424.00 362.00 340.00 328.00 4,648.00 387.33

SPRM 522.00 472.00 421.00 416.00 586.00 718.00 716.00 772.00 625.00 428.00 449.00 473.00 6,598.00 549.83

SPS 3,703.00 3,559.00 3,278.00 3,348.00 4,050.00 5,113.00 5,121.00 5,575.00 4,758.00 3,678.00 3,547.00 3,537.00 49,267.00 4,105.58

WFEC 1,365.00 1,174.00 1,053.00 804.00 1,068.00 1,268.00 1,239.00 1,332.00 1,131.00 824.00 969.00 1,063.00 13,290.00 1,107.50

WR 3,951.00 3,506.00 3,147.00 3,170.00 4,192.00 5,129.94 5,338.63 5,745.90 4,544.74 3,455.00 3,291.00 3,465.00 48,936.21 4,078.02

Region 34,883.72

SCHEDULE 1SCHEDULING, SYSTEM CONTROL AND DISPATCH SERVICE

Scheduling, System Control and Dispatch Service is required to schedule the movement

of power through, out of, within or into a Control Area. Charges for such service shall be as

follows:

1) For Customers taking Firm or Non-Firm Point-To-Point Transmission Service, for through

and out transactions, the Schedule 1 charge shall be the product of the capacity reserved,

expressed in MW and the appropriate rate as follows:

On-Peak:

Monthly Rate $59.2979 per MW-Month

Weekly Rate $13.6841 per MW-Week (The Monthly Rate times 12, divided by 52)

Daily Rate $2.7368 per MW-Day (The Monthly Rate times 12, divided by 260)

Hourly Rate $0.1711 per MW-Hour (The Monthly Rate times 12, divided by 4160)

Off Peak:

Daily Rate/MW $1.9495 per MW-Day (The Monthly Rate times 12, divided by 365)

Hourly Rate/MW $0.1711 per MW-Hour (The Monthly Rate times 12, divided by

8760)

On-Peak and Off-Peak Periods

Off-Peak days shall be Saturdays and Sundays and all NERC holidays. All other

days shall be On-Peak. All hours during Off-Peak days shall be Off-Peak. On-Peak

hours during On-Peak days shall be all hours from HE 0700 through HE 2200 Central

Prevailing Time. All other hours during On-Peak days shall be Off-Peak.

2) For Customers taking Firm or Non-Firm Point-To-Point Transmission Service, for

transactions into and within the Transmission System, the Schedule 1 charge shall be the

charge computed pursuant to the approved rate schedule of the Zone that is the Point of

Delivery.

3) For Customers taking Network Integration Transmission Service, the Schedule 1 charge shall

be the charge computed pursuant to the approved rate schedule of the Zone in which the load

is located.

ADDENDUM 1 TO SCHEDULE 1Revenue Requirements for the Allocation of Through And Out Transaction Revenue

Revenue associated with the provision of Schedule 1 service for Customers taking Firm or Non-Firm Point-To-Point Transmission Service for through and out transactions, shall be allocated to Transmission Owners in proportion to the respective scheduling revenue requirement of each such Transmission Owner associated with the provision of this service. Such scheduling revenue requirements are:

CURRENTLY EFFECTIVETransmission Owner Revenue Requirement

AEP$5,425,257

KCP&L Greater Missouri Operations Company $194,469Mid-Kansas Electric Company $500,053 Empire $260,944 GRDA $686,880 KCPL $ 732,303Midwest $190,804 OG+E $4,759,216 SPA $2,614,172 Springfield $0 SPS $1,903,138Westar $3,209,760 WFEC $1,824,120 Lincoln Electric System See Attachment H Section II.6.Nebraska Public Power District $6,522,245Omaha Public Power District See Attachment H Section II.5.

Addendum 1 to Schedule 11

Rate Sheet for Region-Wide 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 set forth below:

1. Annual Rate: $1,425.8569/MW of Reserved Capacity per year.

2. Monthly Rate: $118.8214/MW of Reserved Capacity per month.

3. Weekly Rate: $27.4203/MW of Reserved Capacity per week.

4. Daily Rate:

On-Peak: $5.4841/MW of Reserved Capacity per day.

Off-Peak: $3.9172/MW of Reserved Capacity per day.


The Transmission Customer shall compensate the Transmission Provider for

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

set forth below:



3. Daily Rate:


Off-Peak $3.9065/MW of Reserved Capacity per day.

4. Hourly Rate:

On-Peak: $0.3428/MW of Reserved Capacity per hour.

Off-Peak $0.1628/MW of Reserved Capacity per hour.

Total Region-wide Charge

The total Region-wide Charge paid by a Transmission Customer pursuant to a

reservation for hourly delivery shall not exceed the above on-peak daily rate multiplied

by the highest amount of Reserved Capacity in any hour during such day. The total

Region-wide Charge in any week, pursuant to a reservation for hourly or daily delivery,

shall not exceed the above Region-wide Rate specified for weekly delivery multiplied by

the highest amount of Reserved Capacity in any hour during such week.

On-Peak and Off-Peak





Addendum 2 to Schedule 11

Rate Sheets for Base Plan Zonal Point-To-Point Transmission Service

American Electric Power – West Zone




1. Yearly Rate: $2,538.1010/MW of Reserved Capacity per year.



4. Daily Rate:






set forth below:



3. Daily Rate:



4. Hourly Rate:



Total Zonal Base Plan Charge

The total zonal charge paid by a Transmission Customer for each Zone pursuant

to a reservation for hourly delivery shall not exceed the above on-peak daily rate

multiplied by the highest amount of Reserved Capacity in any hour during such day. The

total zonal charge for each Zone in any week, pursuant to a reservation for hourly or daily

delivery, shall not exceed the above Base Plan Zonal Rate for the Zone specified for

weekly delivery multiplied by the highest amount of Reserved Capacity in any hour

during such week.






KCP&L Greater Missouri Operations Company Zone




1. Yearly Rate: $571.7294/MW of Reserved Capacity per year.



4. Daily Rate:






set forth below:



3. Daily Rate:



4. Hourly Rate:




The total zonal charge paid by a Transmission Customer for each Zone pursuant

to a reservation for hourly delivery shall not exceed the above on-peak daily rate

multiplied by the highest amount of Reserved Capacity in any hour during such day. The

total zonal charge for each Zone in any week, pursuant to a reservation for hourly or daily

delivery, shall not exceed the above Base Plan Zonal Rate for the Zone specified for

weekly delivery multiplied by the highest amount of Reserved Capacity in any hour

during such week.






City Utilities of Springfield, Missouri Zone


The Transmission Customer shall compensate the Transmission Provider

each month for Reserved Capacity at the sum of the applicable charges set forth

below:




4. Daily Rate:





for Non-Firm Point-To-Point Transmission Service up to the sum of the

applicable charges set forth below:



3. Daily Rate:



4. Hourly Rate:




The total zonal charge paid by a Transmission Customer for each Zone

pursuant to a reservation for hourly delivery shall not exceed the above on-peak

daily rate multiplied by the highest amount of Reserved Capacity in any hour

during such day. The total zonal charge for each Zone in any week, pursuant to a

reservation for hourly or daily delivery, shall not exceed the above Base Plan

Zonal Rate for the Zone specified for weekly delivery multiplied by the highest

amount of Reserved Capacity in any hour during such week.


Off-Peak days shall be Saturdays and Sundays and all NERC holidays.

All other days shall be On-Peak. All hours during Off-Peak days shall be Off-

Peak. On-Peak hours during On-Peak days shall be all hours from HE 0700

through HE 2200 Central Prevailing Time. All other hours during On-Peak days

shall be Off-Peak.

Empire District Electric Company Zone



each month for Reserved Capacity at the sum of the applicable charges set forth

below:




4. Daily Rate:





for Non-Firm Point-To-Point Transmission Service up to the sum of the

applicable charges set forth below:



3. Daily Rate:



4. Hourly Rate:



Total Zonal Base Plan