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Resolution - 4183 - Notice Of Public Hearing - SPEC - Rate Change - 06_24_1993
Resolution No. 4183 June 24, 1993 Item #24 ORDER WHEREAS, a notice of intent to change electric rates within the City of Lubbock was heretofore filed with the City Secretary of the City of Lubbock by South Plains Electric Cooperative; and WHEREAS, it has been determined that such rate change is a major change within the meaning of Vernon's Ann.Civ.St., Article 1446c; and WHEREAS, the City Council, sitting as a regulatory authority, is required to conduct a hearing with regard to major rate changes within the City of Lubbock; and WHEREAS, such hearing was commenced on May 13, 1993, and continued through June 24, 1993, at the request of South Plains Electric Cooperative; and WHEREAS, revised tariffs have been filed by South Plains Electric Cooperative with the City Secretary on May 25, 1993, to incorporate changes recommended by the Public Utility Commission staff; NOW THEREFORE: BE IT ORDERED BY THE CITY COUNCIL OF THE CITY OF LUBBOCK: THAT the City Council of the City of Lubbock, sitting as a regulatory authority under applicable provisions of the Public Utility Regulatory Act, Vernon's Ann.Civ.St., Art. 1446c, after due consideration of the evidence and testimony presented in a regula hearing conducted in this matter, hereby approves the implementati of t revised tariffs filed by South Plains Electric Cooperative imm iately or s hereafter as shall be deemed practicable by the compa y. ,, Ordered by the City Council as ala �ru June, 1993. / ATTEST: Betty o sCity Secretary APPROVED AS TO CONTENT: Kodert Massengale, AssisP Manager/Financial Services gEFROV D AS TO FORM: h/ C -)A OS �� VQ � - z -m&-, Z: I Ddf4ld G. Va—ffid—WW, First Assistant' City Attorney 24 4 day of DGV:dw/agenda-D2/SPEC.ord rev. Ame 17. 1993 r I. i LAW 014ICES McGiNNIS, LOCIiEIDGE & KILGORE, 1300 CAPITOL CENTER 26S0 TEXAS COMMERCE TOWER Gil® CONGRESS AVENUE 8 300 CHARLES COURT 600 TRAVIS STREET AUSTIN, TEXAS 78701 205 NORTH PRESA STREET HOUSTON, TEXAS 77002 SAN ANTONIO, TEXAS 75205 (713) 227-6000 (512) 465-6000 (210) 226-4231 RAX (713) Z38-8505 RAX (512) 425-6003 rAX (210) 226-1015 rRITES'S wNECT "L MUMSEW (512) 495-5046 August 4, 1993 Mr. Jim/ftoberts South ains Electric Cooperative, Inc. P.O. rawer 1830 Lub ck, Texas 79408 RECEIVED AUG 0 9 1993 MAYOR'S OFFICE Re: PUC Docket No. 11904; Application of South Plains Electric Cooperative, Inc., for Expedited Authority to Change Rates Pursuant to PUC Subst. R. 23.23(c) Dear Jim: Enclosed for your files are tariff section 20, sheets 1 and 26, that were inadvertently omitted from the tariff recently approved as a result of your expedited rate case. Please include these tariff pages in your official tariff on file at your office and all other copies of the current tariff. If you have any questions about this matter, please don't hesitate to give me a call. Yours very truly, Campbell McGinnis ECM/lm Enclosure cc: Jack Moss AUG 1993 41n 5 Pubffc Utiffty Commission of Texas Co n ao er 7800 Shoal CreeZt 6u evard , r. Robert W. Gee Austin, Texas 78757 • 512/458-0100 Chairman 1333 JUL 27 F-11 4' 00 Karl R. Rfibago Commissioner July 27, 1993 Mr. Campbell McGinnis Attorney for South Plains Electric Cooperative, Inc. 1300 Capitol Center 919 Congress Avenue Austin, Texas 78701 Res Tariff Control No. 12128, Application To Correct Tariff Items In The Tariff Filing Pursuant To The Final Order In Docket No. 11904. Dear Mr. McGinnis: NOTICE OF APPROVAL Pursuant to the recommendations of General Counsel and the Commission Staff filed on July 20, 1993, the tariff sheets filed June 24, 1993, are APPROVED as of the date of this letter. Sincerely, amx. lmjrr-� Susan Thomas Morton Administrative Law Judge Public Utility Commission of Texas Memorandum, 5 7 . - TO: Central Records - Tariff FROM: Michael E. Etchison -- Assistant General Counsel DATE: July 20, 1993 RE: Electric Control No. 12128 - Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. R. 23.23(c); PUC Docket No.11904 General Counsel having considered the recommendation to approve of Staff witness Stephen Benenson, attached hereto, General Counsel has concluded that the tariff as submitted should be approved, and so recommends. MEE/j-1 N:\ME&L'I\1212&l.D0C &,& Utility Gcrmmission . "+ as Memorandum RECEIVED JUN 2 81993 ►'UBUl; -AL11Y CUM -MISSION Electric General Counsel By FROM: Central Records - Tariffs Activity Code _223 Electric Control No. w 12128 Effective Date 07/29/93 Utility Name SOUTH PLAINS ELECTRIC COOPERATIVE. INC. GENERAL COUNSEL MUST FILE STAFF"S RECOMMENDATIONS BY 07/22/93 saesassesssssassssssseasessarsssssssssssassesssssessssesssasessssss�ssssassas■ STAFF RECOMMENDATION DATE J� 3 T0: FROM: This filing has been reviewed and it is recommended that the filing be: ILr-Xpproved as filed ( } Docketed t } Approved as revised ( } Suspended ( } Rejected ( } Received Comments: c:%WMD &=S%rMHS.0= LAW OFFICES MCGIwwis, Locmui)oE 4ULGo.'IR35-, L.L.P. `�- 1300 CAPITOL CENTER 2850 TEXAS COMMENCE TOWER Oil; CONGRESS JUtY �F� �• �� 6 300 CHARLES COUNT 600 TRAVIS STNEET I AUSTIN, TEXAS 7870L 205 NORTM PPESA STREET HOUSTON. TEXAS 77002 �.t[� _ rtir 1 C n (512) s054;;J IC UTIL; 1 • 00, i,15„ION SAN ANTONIO, TEXAS 76205 (713) 227.6000 PAx (512) t05•aooaFiLf!ii. CLCfZ�: (210) 226.xA 1231 �A1c (713) 238.8583 rAX (210) 226-1010 w0breWs Diew a.& r„w« (512) 495-6046 June 24, 1993 Mr. Garvis Cunningham Central Records Department Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Garvis: Recently, you stamped "approved" on the revised tariffs of South Plains Electric Cooperative in the above -captioned proceeding. Your assistance in approving the Cooperative's tariffs promptly is most deeply appreciated. Unfortunately, 2 pages were omitted. Enclosed for approval in the above -captioned matter are sheets 1•and 26 of Section 2, the rate schedules, for South Plains Electric Cooperative. Please file these tariff sheets and return one copy of each page, bearing the Commission's stamp of approval, to our office at your earliest convenience. Thank you for your attention to this matter. Yours very truly, Camp ell McGinnis ECM/lm Enclosures cc: General Counsel, PUC Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative 8:\3\ffPLLW3\RATE\FUCM N5-= ' SOUTR PLAINS ELECTRIC COOPERATIVE, INC. Tarif f for Section 20 Sheet No. 1 Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustments . . . . . . . 2 .02 Residential Service . . 0 4 .03 Large Power . . . . . . . . . . . . . . . 7 .04 Irrigation Service . . . . . . . . . . . . . 10 .05 General Service . . . . . . . . . . . . . . . . 14 .06 Cotton Gin Service . . . . . . . . . . . . . . 16 .07 Oil Field Service -Secondary Voltage . . . . . . 19 .08 Primary Service Voltage . . . . . . . . . . . . 21 .09 Outdoor Lighting Service . . . . . . . . . . . 24 .10 Public Street Lighting Service . . . . 27 .11 Demand Side Management . . . 0 . . 29 u PUBLIC UTILITY COMMISSION OF TEXAS APPROVED JAIL Z7 '93 DOCKET CONTROL # TARIFF CLERK N 1 5 .'1 ' SO= PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Section 20 Sheet No. 26 Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Payment Each bill for utility service (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date suuch bill is due, the customer's account. will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. PUBLIC UTILITY COMMISSION OF TEXAS APPROVED JUL 2 7 '93 IOC?Zr CONTROL ## r,r. TARIFF CLERK LAWOFFICES MCGINms, I,OCHRIDGE & KILGORE, L.L.P. 1300 CAPITOL CENTER 2850 TEXAS COMMERCE TOWER 600 TRAVIS STREET HOUSTON, TEXAS 77002 (713) 227. 6000 FAX (713) 238 • 8585 Mr. Robert Massengale City of Lubbock P.O. Box 2000 Lubbock, Tx 79547 919 CONGRESS AVENUE AUSTIN, TEXAS 78701 (512) 495-6000 FAX (512) 495-6093 WRITERS DIRECT DIAL NUMBER: (512) 495-6046 June 25, 1993 B 300 CHARLES COURT 205 NORTH PRESA STREET SAN ANTONIO, TEXAS 7a2OS (210) 226 - 1231 FAX (210) 226 - 1019 Re: Application of South Plains Electric Cooperative, Inc. for Authority to Change Rates Dear Mr. Massengale: At the City Council meeting on June 24, 1993, the City Council approved revised rates for South Plains Electric Cooperative, Inc. The revised rates consist of those tariff pages which have previously been approved by the Public Utility Commission of Texas and filed with the City together with the two pages which are enclosed. I would deeply appreciate -it if you would send me a copy Qf ""3 City ordinance approving South Plains' implementation of revise ra es. My recollection that the rates will be effective as of June 17, 1993 to coordinate with the PUC authorized implementation date for areas outside the city. Your personal attention to the Cooperative's rate case as well as the personal attention of Don Vandiver has helped make the City Council's consideration of the Cooperative's rate request go smoothly. The Cooperative deeply appreciates your assistance in shepherding this matter to conclusion. I look forward to working with you and with the City again. Yours very truly, Campbell McGinnis ECM/dlm Enclosures cc: Don Vandiver 8:\S\SPLAINS\RATE\MASSENG3.LTR Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAID RATE SCSEDULES APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUS -SECTION SUBJECT .01 Billing Adjustments . . . . . . . . . . . . . . . 2 .02 Residential Service . . . . . . . . 4 .03 Large Power ... 7 .04 Irrigation Service . . . . . . 10 .05 General Service 14 .06 Cotton Gin Service 16 .07 Oil Field Service -Secondary voltage 19 .08 Primary Service voltage . . . . . . . . 21 .09 Outdoor Lighting Service . . . . . . . . . . . 24 .10 Public Street Lighting Service . . . . . . . . 27 .11 Demand Side Management . . . . . . . . . . . . 29 %V am Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLE: I PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and. subject tc disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. ' Section Sheet No. SOOTS PLAINS ELBCTRIC COOPERATM, INC. 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STATE RATE SCHEDULES APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustment■ . . . . . . . 2 .02 Residential Service . 4 .03 Large Power .. . 7 .04 Irrigation Service . 10 .05 General Service @ 14 .06 Cotton Gin Service 16 .07 Oil Field Service -Secondary Voltage 19 .08 Primary Service Voltage . . . . . . . . . . . . 21 .09 Outdoor Lighting Service . . . . . . . . . . . 24 .10 Public Street Lighting Service . . . . . . . . 27 .11 Demand Side Management . . . . . . . . . . . 29 N �i Section Sheet No. • SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC sTArsP RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. JM r Section Sheet No. SOUTH PLAINS KLECTRIC COOPSRATM, INC. 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLEI PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustments . . . . . . . 2 .02 Residential Service . . . . . . . . . . . . . . . 4 .03 Large Power ... 7 .04 Irrigation Service 10 .05 General Service 14 .06 Cotton Gist Service . . 16 .07 Gil Field Service -Secondary Voltage . . . . . . 19 .08 Primary Service voltage . . . . . . . . . . . . 21 .09 Outdoor Lighting Service . . . . . . . . . . . 24 .10 Public Street Lighting Service . . . . . . . . 27 .11 Demand Side Management . . . . . . . . . . . . 29 N am Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLE% PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. am r ,y Section Sheet No. • SOUTE PLAINS ELECTRIC COOPERATIVE, INC. 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHMU'LES APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustments . . . . . . . . 2 .02 Residential Service . . . . . . . . . . . . . . . 4 .03 Large Power 9 .04 Irrigation Service . . . . . . . . 10 .05 General Service . . . . . . . . . . 14 .06 Cotton Gin Service . . . . . . . . 16 .07 Oil Field Service -Secondary Voltage . . . . 19 .08 Primary Service Voltage . . . . . . . . . . . . 21 .09 Outdoor Lighting Service . . . . 24 .10 Public Street Lighting Service . 27 .11 Demand Side management . . . . . . . . . . . . 29 N MEM I . L • Section Sheet No. SOUM PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMPRATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. 3M Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIW, INC. 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustments . . . . . . 2 .02 Residential Service . . . 4 .03 Large Power . '. 7 .04 Irrigation Service 10 .05 General Service 9 . . . 14 .06 Cotton Gin Service 16 .07 Oil, Field service -Secondary voltage 19 .08 Primary Service Voltage . . . . . 21 .09 Outdoor Lighting Service . . . . 24 .10 Public Street Lighting Service 0 27 .11 Demand Side Management . . . . . . . . . . . . 29 r Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLEt PUC STAMP. RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service (s) , regardless of the nature of the ,service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and. subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penaltv Reference Tariff Section 30.03. LAW OFFICES MCGINNIS, LOCHBIDGE & KILGORE, L.L.P. 1300 CAPITOL CENTER 2850 TEXAS COMMERCE TOWER 600 TRAVIS STREET HOUSTON, TEXAS 77002 (713) 227.6000 PAX (713) 238 - 8565 Mayor a Governing City o Lubbock P.O. B x 2000 Lubbo k, Tx 79547 Body Att : Robert Massengale 919 CONGRESS AVENUE AUSTIN, TEXAS 78701 (512) 495-600C PAX (512) 495-6023 W*ffl**S MOCCT DIA1. NW.11CA: (512) 495-6046 May 24, 1993 ® 300 CHARLES COURT 205 NORTH PRESA STREET SAN ANTONIO, TEXAS 7020S (210) 226.1231 PAX (210) 226.4019 I�e.ce5 �l43 Re: Application of South Plains Electric Cooperative, Inc. for Authority to Change Rates; PUC Docket No. 11904 Dear Mayor and Members of Council: South Plains Electric Cooperative hereby amends it filing in the above -captioned proceeding to request approval of the enclosed tariffs in lieu of the tariffs in its original filing. The Staff of the Public Utility Commission of Texas has recommended approval of the enclosed tariffs which contain minor rate design changes. We expect that the Public Utility Commission will approve the rates recommended by its staff on June 2, 1993. In order to have uniform system -wide rates which are the same inside the City of Lubbock and in rural areas, we are requesting that the enclosed tariffs be adopted at the meeting of the City Council scheduled for May 27, 1993. Your assistance in this matter is most deeply appreciated. Yours very truly, Campbell McGinnis ECM/lm Enclosure cc: Jim Roberts Jack Moss Don Vandiver We're Sorry We tried to deliver ❑ pick up a shipment of —L packages. Toll free number If you are in: U.S. 800 238-5355 Canada 800 463-3339 We were here at_'ifM. onDWA Z A.M. ❑ We'll return before C�`�,P. on .MQ ` %. e left your shipment at ( �" a 1 J' !" r PACKAGE TRACKING NUMBER(S) If you can't be here when we return and want your shipment left, please sign below at the "x" and leave this form on your door for your couder.(By Law. FederalPostal mwa=� Wave We could not leave your shipment because: imiages in ❑ It is marked "Bill Recipient." We must have your FedEx account number. Please provide your account number here: ❑ it is a C.O.D. shipment Please call us about your shipment ❑ Check here and complete the back of this form if you would like to be on a permanent program that will allow us to leave packages for you without a signature. Leave this completed form on your door for your courier. If you need to make other arrangements or If you would like to pick up your package, call us at 800 238-5355 if you're in the U.S.; Canada 800 463-3339. After 3 delivery attempts, packages will be returned to the shipper. "W OFFICES MCGINNIs, LOCHBIDGE & KILGO$E, LL- 1300 CAPITOL CENTER 2880 TEXAS COMMERCE TOWER 600 TRAVIS STREET HOUSTON, TEXAS 77002 (713) 227-6000 1PAX (713) 238.8585 Mayor a Governing City o Lubbock P.O. x 2000 Lubbo k, Tx 79547 Body Att : Robert Massengale 910 CONGRESS AVENUE AUSTIN. TEXAS 767o1 (512) 4®S-6000 FAX (512) 403-6003 wwnan's MOM? aK "User. (512) 495-6046 May 24, 1993 6 300 CHARLES COURT 205 NORTH PRESA STREET SAN ANTONIO, TEXAS 7.20E (210) 226.1231 /AX (210) 226 •1016 Rmce5 �lg3 Re: Application of South Plains Electric Cooperative, Inc. for Authority to Change Rates; PUC Docket No. 11904 Dear Mayor and Members of Council: South Plains Electric Cooperative hereby amends it filing in the above -captioned proceeding to request approval of the enclosed tariffs in lieu of the tariffs in its original filing. The Staff of the Public Utility Commission of Texas has recommended approval of the enclosed tariffs which contain minor rate design changes. We expect that the Public Utility Commission will approve the rates recommended by its staff on June 2, 1993. In order to have uniform system -wide rates which are the same inside the City of Lubbock and in rural areas, we are requesting that the enclosed tariffs be adopted at the meeting of the City Council scheduled for May 27, 1993. Your assistance in this matter is most deeply appreciated. Yours very truly, Campbell McGinnis ECM/lm Enclosure cc: Jim Roberts Jack Moss Don Vandiver ( We're' Sorry We tried to deliver ❑ pickup a shioment of --L— oackaoes. J/ We were here at .M. on Date AM. ❑ We'll return before P.M. on e 1eft your shipment at Toll free number If you are in: U.S. 800 238-5355 Canada 800 463- 3339 PACKAGE TRACKING NUMBER(S) If you can't be here when we return and want your shipment left, please sign below at the V and leave this form on your door for your courier. (Ely Low,In Mailboxes.)cannot - We could not leave your shipment because: ❑ It is marked "Bill Recipient." We must have your FedEx account number. Please provide your account number here: ❑ It is a C.O.D. shipment. Please call us about your shipment. ❑ Check here and complete the back of this form If you would like to be orra permanent program that will allow us to leave packages for you without a signature. Leave this completed form on your door for your courier. By signature, I am requesting that Federal Express leave this shipment at this +�nt Federal Express wid not be . I agree that - . damage that results from leaving the shipment as I have requested. (Please sign in black or blue ink.) If you need to make other arrangements or if you would like to pickup your package, call us at 800 238-5355 if you're in the U.S.; Canada 800 463-3339. After 3 delivery attempts, packages will be returned to the shipper. A DOCKET NO. 11904 APPLICATION OF SOUTH PLAINS § �PU' b6i,'TILI1Y COMMISSION ELECTRIC COOPERATIVE, INC. § FOR EXPEDITED AUTHORITY § OF TEXAS TO CHANGE RATES PURSUANT § TO P.U.C. SUBST. R. 23.23(c) § GENERAL COUNSEL'S APPROVAL OF PROPOSED TARIFF SHEETS The General Counsel of the Public Utility Commission of Texas, representing the public interest, recommends approval of the proposed tariff sheets submitted on May 12, 1993, by South Plains Electric Cooperative, Inc. The memorandum of Staff witness Stephen M. Benenson memorializing his approval is attached hereto. MEE/gb K\M1T'PL\11904-0KI3oC Respectfully Submitted, Nolan F. Ward j General V el Bret Slocum ' Deputy G neral ounsel Nrichaeyb. Mcnison Asiistabt General Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd., Suite,109W Austin, Texas 78757 (512) 458-0278 I t DOCKET NO. 11904 CERTIFICATE OF SERVICE I hereby certify that a true and correct copy of the above and foregoing General Counsel's Approval of Proposed Tariff Sheets was mailed this May 24, 1993, by First Class, U.S. Mail, Postage Pre -paid to: SOUTH PLAINS ELECTRIC COOPERATIVE, ASSOC. MEE/gb 0.\mee_.c\11904 Campbell McGinnis McGinnis, Lochridge & Kilgore 1300 Capi Center 919 Co res /Went Austin exa, 787b1 j 6. Mcntsorr ' V General Counsel Public Utility Commission of Texas 7800 Shoal Creels Boulevard Austin, Texas 78757 (512) 458-0278 LAW OrrxCEs McGiNwis, LOCHBIDGE & KILGORE, ti.p 1300 CAPITOL CENTER SOSO TEXAS COMMERCE TOWER 019 CONGRCS$ AVENUE too TRAVIS STREET AUSTIN, TEXAS 7870L NOUSTON. TEXAS 77002 (713) ZZ7.6000 (SIR) .495-6000 PAX (713) Z36.6365 ♦AX (SIX) 495-6003 wun.'s e.,Cv 0. � "user (512) 495-6046 May 12, 1993 Mr. Michael Etchison Assistant General Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 0 300 CNARLES COURT SOS NORTH PRESA STREET SAN ANTONIO. TEXAS 76203 (SIO) 226-I931 FAX (Zlo) ZZa - 1019 RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Mr. Etchison: Enclosed is a draft of rate schedules which have been revised to conform with with the staff recommendations in the above - captioned proceeding. Please request that the staff review the enclosed rate schedules to be sure that there are no errors and advise me of the results of their review. If the? tariffs are acceptable, I would like to have them filed as agreed tariffs in the above -captioned proceeding with the request for implementation upon Commission final order. Thank you for your assistance in this matter. Yours very truly, Campbell McGinnis ECM/lm Enclosures cc: Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative s S \S \SPL&=5\M=\ETCFiIS=. LTA SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Section Sheet No. 20 1 Revision Page 1 TABLE OF CONTENTS SUB -SECTION - -SUBJECT .01 Billing Adjustments . . . . . . . . . . . . . 2 .02 Residential Service . . . . . . . . . . . . . . . 4 .03 Large Power . . . . . . . . . . . . . . . . . 10 .04 Irrigation Service . . . . . . . . . . . . . 13 .05 General Service . . . . . . . . . . . 17 .06 Cotton Gin Service . . . . . . . . . . . . 19 .07 Oil Field Service -Secondary voltage . . . . . . 22 .08 Primary Service voltage . . . . . . . . . . 24 .09 Outdoor Lighting Service . . . . . . . . . . . 27 .10 Public Street Lighting Service . . . . . . . . 30 .11 Demand Side Management . . . . . . . . . 32 L Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 2 Tariff for Electric Service Revision Page 1 SECTION TITLEs PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .01 BILLING ADJUSTMENTS The Cooperative shall adjust all bills in accordance with the following adjustments if applicable. The Power Cost Recovery Factor (PCRF) shall be applied to each RWH sold in addition to any monthly minimum, contract Minimum, or annual minimum charges and shall not apply toward satisfying any of said minimum charges. Power Cost Recovery Factor (PCRF) The monthly charges shall be increased or decreased on a uniform per lKWH basis computed monthly as,follows: PCRF : (A-B+C)/BWHs (A-B-C)/RWHs Where: PCRF - Power Cost Recovery Factor (expressed in SIEWH) to be applied to estimated energy sales for the billing period. A Total estimated purchased electricity cost from all suppliers including fuel for the billing period. B = Total estimated purchased electricity cost from all suppliers including fuel which are included in the Cooperative base rates. The base power cost is computed ass B a (D) (RWHs) D a Base power cost in $/RWH sold of $0.042135 for all billing months. C Adjustment to be applied to the current monthly billing to account for differences in actual purchased electricity costs and actual PCRF revenues recovered in previous periods. SOUTH PLAINS ELECTRIC COOPSRATIVB, INC. Tariff for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS KWHs 0 Total estimated energy sales for billing period. NOTE: BASE POWER COST a COST OF PURCHASED POWER TOTAL KWH SALES 13,386,267 s 0.042135 317,702,856 Section Sheet No. 20 3' Revision Page 1 0 ' SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Section 20 Sheet No. 4 Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .02 RESIDENTIAL SERVICE Availability Available to Customers for all farm, shop and home uses, (single family residence or 1- unit apartment), including lighting, heating, power and home water supply, subject to established rules and regulations, but not applicable for irrigation or seasonal agricultural processing use. Type of Service Single phase and three phase at available secondary voltages. Frequency and voltage shall be subject to reasonable variation. Regular Residential Rate Customer charge: $6.00 per month Energy charges $.05817 per kWh Minimum Charge The minimum monthly charge under the above rate shall be $6.00 where 10 RYA or less of transformer capacity is required, but not including any applicable billing adjustments provided for under Tariff Section 20.01. For members requiring more than 10 KVA transformer capacity, the minimum monthly charge shall be increased at the rate of $1.00 for each additional KVA or fraction thereof required. Payment of the minimum charge shall entitle the member in all cases to the use of the number of kilowatt hours corresponding to the minimum charge in accordance with the rate. Electric Living Service Space Heater — Separate Pieter If the Customer shall elect to have all energy used by such space heating metered separately from other uses, then such separate use will be billed as follows: Customer Charges $0.00 per month Energy Charges November -April $0.03035 per kWh • May -October $0.05817 per kWh I Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 5 Tariff for Electric Service Revision Page 1 SECTION TITLES PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Ism Space Heater - Sincle Meter Customer Charges $6.00 per month Energy Charges - November -April First 500 kWh $0.05817 per kWh Remaining kWh $0.03035 per kWh Hay -October All kWh $0.05817 per kWh Water Heater When Customer has in regular use a permanently installed 240 volt, 20 gallons or greater, storage type water heater of not greater than 5.5 kilowatts, individual rated capacity, billing will be as follows: Customer Charge: $6.00 per month Energy Charges First 500 kWh $0.05817 per kWh Next 500 kWh $0.03873 per kWh Additional kWh $0.05817 per kWh All Electric Space Heat When Customer has in regular use permanently installed space heating equipment of an aggregate rated capacity of 5 kilowatts or more, excluding bathroom heater,. billing will be as follows: Customer Charge: $6.00 per month Energy Charges First SOO kWh $0.05817 per kWh Next 500 kWh $0.03873 per kWh Additional kWh $0.05817 per kWh Space Seat - Water Heater/Space Beater When customer has water heating in combination with all -electric space heating, billing will be as follows: Customer Charges $6.00 per month Section Sheet No. SORTS PLAINS ELECTRIC COOPERATIVE, INC. 20 6 Tariff for Electric Service Revision Page 1 SECTION TITLES I PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS 11 h Energy Charge: November -April First 500 kWh $O.OS817 Next S00 kWh $0.03873 Remaining kWh $0.03035 May -October First S00 kWh $O.05817 Next S00 kWh $0.03873 Remaining kWh $O.OS817 �l D h Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and .subject to disconnection in accordance with the rules of the appropriate regulatory authority. ' SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Section 20 Sheet No. 7 Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .03 LARGE POWER SERVICE Availability _ Available for general and industrial service to Customers, including large schools and churches, having capacity in excess of 50 M for all uses including lighting, heating and power and municipal water pumping, subject to the established rules and regulations; not available for cotton gins, oil well, or irrigation pumping. Type of Service Single-phase and three-phase at available primary or secondary voltagesi motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charge: $50.00 per month; Demand Charges $ 6.00 per kW of billing demand per months plus, p Energy Charge: $ 0.04650 per kWh for first 17S KW $ 0.02622 for all remaining RWh. Power Factor Adjustment The Customer agrees to maintain unity power factor as nearly as practicable. To correct for average power factor lower than ninety-five percent (9S%), for Customers if and when the Cooperative deems necessary, an adjustment will be made by increasing measured demand one percent (1%) by which the average power factor is less than ninety-five percent (9S%) lagging. Minimum Monthly Charge The minimum monthly charge shall be the hi hest one of the following charges as determined for the Customer in question, but not including any applicable billing Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 8 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS adjustments provided for under Tariff Section 20.01. 1. The minimum monthly charge specified in the contract for service. 2. A charge of $1.00 per KVA of installed transformer capacity. Determination of Billing Demand The billing demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered, as indicated or recorded by a demand meter and adjusted for power factor as stated above. Conditions of Service 1. Delivery Point - Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. All wiring, pole lines, and other electric equipment (except the Cooperative's metering equipment) on the load side of the metering point shall be owned and maintained by the Customer. 2. Exclusive Use - Service delivered hereunder is for the exclusive use of the Customer and may not be resold or delivered for the use of others. 3. Metering - When primary metering equipment is used, it shall be located at the delivery point. However, the Cooperative shall have the option of metering at secondary voltage and adding two percent to the metered kilowatt hours to compensate for transformer losses. In the event secondary metering is used, it will be located on the load side of the Customer's transformer structure. Billing Adjustments Reference Tariff Section 20.01. Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 4 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service (s )7, regardless of the nature of the service(s ), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. l Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 10 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .04 rRRIGATION SERVICE RATES Availability Available to Customers of the Cooperative for service to irrigation pumps and subject to the established rules and regulations of the Cooperative covering this service. Type of Service Single or three-phase, 60 cycles, at standard secondary voltages. The Cooperative may limit the maximum rating of motors where such may cause interference to other Customers. Frequency and voltage shall be subject to reasonable variation. Rate Summer (July through September billing) Energy Charge: First 200 kWh per horsepower - $0.12413 per kWh, exclusive of billing adjustments under Tariff Section 20.01, per season. $0.06616 per kWh for all kWh in excess of 200 kWh per horsepower per " season, exclusive of billing adjustments under Tariff Section 20.01. Winter ( October through June billing) Energy Charges $0.05924 cents per kWh per season, exclusive of billing adjustments R under Tariff Section 20.01. Demand Side Management Eligible customers may receive demand side management credits in accordance with the Cooperative's Demand Side Management Rate. 101 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Determination of Horsepower Section Sheet No. 20 1 11 Revision Page 1 The horsepower billing purposes shall be the motor manufacturer's nameplate rating of horsepower output, except that, if the Cooperative so elects, it shall be determined by actual measurements of power input during a period of maximum normal use, less an allowance of ten percent (10%) of input for motor losses. All motors under 5.0 horsepower will be billed at the 5.0 horsepower rate. T Annual Minimum Charge The annual minimum charge under the above rate shall be $15.00 per horsepower of connected load but not less than $75.00 and shall be billed at $2.50 per horsepower per month for the billing months of April through September. In the event electric facilities are initially made available for service for only a portion of the year, such -�- annual minimum will be as follows: a. Service connected in September: b. Service connected in Octobers C. Service connected in November: d. Service connected in December: $6/horsepower, but not less than $30.00 $4/horsepower, but not less than,$20.00 $2/horsepower, but not less than $10.00 No annual minimum Should the total of all monthly billings in a 12 month period be less than the annual minimum charge, the consumer will pay the difference between the total billing exclusive of billing adjustments under Tariff Section 20.01, and the annual minimum charge specified therein. Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 12 Tariff for Electric Service Revision Page 1 SECTION 'TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Standby Irrigation Service To defer or prevent the Cooperative from retirement of an idle irrigation service for a period of one year or less, the Customer may place an irrigation service on standby. The Cooperative will disconnect the service and may remove the meter and transformers for use elsewhere. Idle Service Annual Charge: $10.00 per horsepower per year, but not less than $50.00 nor more than $300.00, billed not later than April 15 each year, plus; Reconnect Fee: $25.00 With a minimum of seventy-two (72) hours notice, the Cooperative will reconnect the facility, so that the Customer may receive electric service under one of the above rates. Should the Customer have the standby service changed to an active service later in the irrigation year, any amounts paid as Idle Service Charges (except Reconnect Fee) shall be allowed toward the applicable Annual Minimum Charge above. Power Factor Adjustment The Customer agrees to maintain unity factor as nearly as practicable. The horsepower for billing purposes will be adjusted for Customers with 50 horsepower or inure to correct the average power factors lower than ninety-five percent (9S%), and may be so adjusted for other Customers if and when the Cooperative deems necessary. Such adjustments will be made by increasing the horsepower one percent (1%) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each -bill for utility service(s), regardless of the nature of the service(s), is due upon Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 13 Tariff for Electric Service Revision Page 1 SECTION TITLES PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS. receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03 Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 14 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS AS GENERAL SERVICE Availability Available for commercial, industrial, municipal water systems, apartment houses, and three-phase service having a capacity of 50 RVA or less, for all uses including lighting, heating and power, subject to the established rules and regulations. Rate is not available for cotton gins, oil wells or irrigation pumping. Type of Service Single-phase and three-phase at available secondary voltages motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charge: $17.95 per month Energy Charge: $ O.OS908 for all kWh per month , Minimum Monthly Charge The minimum monthly charge under the above rate shall be $17.95 where 10 =A or less of transformer capacity is required, but not including any applicable billing adjustments provided for under Tariff Section 20.01. For Customers requiring more than 10 KVA of transformer capacity, the minimum monthly charge shall be increased by $1.00 for each additional R'VA or fraction thereof required. Minimum Annual Charge for Seasonal Service Customer requiring service only during certain seasons not exceeding nine months per year may guarantee a minimum annual payment of twelve times the minimum monthly charge determined in accordance with the foregoing section, in which case there will be no minimum monthly charge. Is e Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 15 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS Space Heating When a Customer regularly uses pezmanently installed electric heating equipment, 5 KW or more of total capacity in one building and energy for the space heating equipment is measured by a separate meter, all kWh so metered during the November, December, January, February, March and April billing periods will be billed at $0.02660 per kWh subject to the following conditions: 1. The Customer's wiring will provide for a main service meter to measure kWh used for all purposes except space heating and air conditioning compressors, and further provide for a separate meter to measure only energy used exclusively for space heating equipment and air conditioning compressors. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. IS Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 16 Tariff for Electric Service Revision Page 1 SECTION TITLES PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .06 COTTON GIN SERVICE Availability Available for power service to cotton gins and supplemental uses, and for other seasonal uses, excluding energy for standby or shared service with another source of electric power (except qualifying facility). Type of Service Three-phase, 60 hertz, A.C. at Cooperative's available voltagev. Service supplied hereunder will be at a single point of delivery and measured through one meter. Frequency and voltage shall be subject to reasonable variation. Rate r 1 Monthly Service Availability Charge: $50.00 Summer Season (April through September Billing): Demand Charge: $8.00 per KW per month plus Energy Charge: $0.03313 per kWh per month Winter Season (October through March Billing): Energy Charge: First 100 kWh per KW of demand per month $0.07604 per kWh D All additional kWh per month $0.03541 per kWh /� t SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: I PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Annual Minimum Charge Section Sheet No. 20 1 17 Revision I Page 1 The annual minimum charge under the above rate shall not be less than $S.SO per connected KVA, but not including any applicable billing adjustments provided under Tariff Section 20.01. Should the total of all monthly billings be less than the annual minimum charge, the Customer will be billed for such difference with the March billing of the year. Off -Season Disconnection Customer is encouraged to disconnect the service during the Summer months that the service is not required. However, one temporary reconnect will be made for a period not to exceed 24 hours for motor teat, provided the Cooperative is not experiencing a loading peak on the substation furnishing service to the load. Any kWh used will be billed. KW demand will not be billed] the demand register will be reset. Additional temporary reconnects will be made and billed at $25.00. Determination of KW Demand The demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month in which service is rendered hereunder as indicated or recorded by a demand meter adjusted for power factor. Power Factor Adjustments The Customer agrees to maintain unity power factor as nearly as practicable. The KW demand will be adjusted for Customers to correct for average power factors lower than ninety-five percent (95%), if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (1%), for each one percent (li) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adjustments Reference Tariff Section 20.01. Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE; INC. 20 19 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service(e), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. if full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. f f SOUTH PLAINS ELECTRIC COOPERATM, INC. Tarif f for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDME APPLICABLE TO ALL AREAS .07 OIL FIELD SERVICE - SECONDARY VOLTAGE Availability Section Sheet No. 20 1 19 Revision ! Page 1 Available to Customers of the Cooperative for service to oil well pumps (well head service) and for other uses directly related to oil production where energy is used exclusively by electric motors and subject to the Cooperative's rules and regulations covering this service. Type of Service Single-phase or three-phase, 60 hertz, at standard secondary voltage. The Cooperative may limit the maxima, horsepower rating of motors served with single-phase service where such may cause interference to other Customers. Frequency and voltage shall be subject to reasonable variation. Rate Horsepower Charge: $6.00 per horsepower per month, plus, p Energy Charge: $0.03348 per kWh per month. Determination of Horsepower The horsepower for billing purposes shall be the manufacturer's motor nameplate rating, or at its option, the Cooperative may determine the horsepower by test under conditions of maximum operating load. Power Factor The Customer agrees to maintain unity power factor as nearly as practical. The horsepower for billing purposes will be adjusted to correct for average power factors lower than ninety-five percent (95%) if and when the Cooperative deems necessary. Such adjustments will be made by increasing the horsepower one percent (1%) by which the average horsepower is less than ninety-five (95%) lagging. Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 20 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Minimum Monthly Charge The minimum monthly charge under the above rate shall be the horsepower charge and in no event shall it be less than $17.95 but not including any applicable billing adjustments provided for under Tariff Section 20.01. Billing Adjustments Reference Tariff Section 20.01. ~ Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .08 PRIMARY VOLTAGE SERVICE Availability Section Sheet No. 20 1 21 Revision � Page 1 Available for oil field pumping or Customer -owned primary distribution systems., Type of Service Three-phase, 60 hertz, at the Cooperative's standard primary distribution voltages. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charges $50.00 per months Demand Charges $7.75 per month KW of billing demand; plus Energy Charge: $0.02752 per kWh per month Determination of Billing Demand I 0 The billing demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as follows: Power Factor Adjustment The Customer agrees to maintain unity power factor as nearly as practicable. Demand charges will be adjusted for Customers to correct for average power factors lower than ninety-five percent (95%) if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (1%) for each one percent (1%) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adjustments Reference Tariff Section 20.01. Section SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 Tariff for Electric Service Revision 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Hinimum Monthly Charge Sheet No. 22 Page The minimum monthly charge shalr be the highest one of the following charges as determined for the Customer in question, but not including any applicable billing adjustments provided for under Tariff Section 20.01. 1. The minimum monthly charge specified in the contract for service. 2. A charge of $1.00 per KVA of installed transformer capacity. Conditions of Service 1. Delivery Point - Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. All wiring, pole line, and other electric equipment (except the Cooperative's metering equipment) on the load side of the metering point shall be owned and maintained by the Customer. 2. Exclusive Use - Service delivered hereunder is for the exclusive use of the Customer and may not be resold of delivered for the use of others. 3. Metering - When primary metering equipment is used, it shall be located at the delivery point. However, the Cooperative shall have the option of metering at secondary voltage and adding two percent (2%) to the metered kilowatt hours to compensate for transformer losses. In the event secondary metering is used, it will be located on the load side of the Customer's transformer structure. Terms of Payment Each bill for utility service (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 23 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATI o INC. 20 24 Tariff for Electric Service Revision Page 1 SECTION TITLE: I PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .09 OUTDOOR LIGHTING SERVICE Availability Available to Customers of the Cooperative, except where prohibited by law or ordinance for dusk to dawn outdoor lighting in close proximity to existing overhead secondary circuits. Also, available to incorporated cities, towns, and villages for delivery and use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to the established rules and regulations of the Cooperative. Type of Service Unmetered electric energy to lighting units, furnished, installed and maintained by the Cooperative. Frequency and voltage shall be subject to reasonable variation. Rate Per Light for Month Light mounted and connected to overhead secondary unit. n 175 Watt Mercury Vapor ; 5-es/month 400 Watt Mercury Vapor ; 8.48/month 100 Watt HP Sodium ; 5.85/month 150 Watt HP Sodium ; 8.48/month N 175 Watt Halide ; 5.85/month N 400 Watt Halide ; 8.52/month N+ 1000 Watt Halide ;17.50/month A Multiple USE Discount 21 through 50 units: over 50 units: Billing Adjustments $0.25 per unit per month $0.50 per unit per month Reference Tariff Section 20.01. Section SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 Tariff for Electric Service Revision 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Conditions of Service 1. 2. 3. 4. S. 6. Sheet No. 2S Page The Cooperative shall furnish, install, operate, and maintain the outdoor lighting equipment including lamp, Iuminaire, bracket attachment and control device on an existing wooden pole of the Cooperative, when one is readily available, electrically connected so that the power for operation of light does not pass through the meter for the customer's other usage, at a location mutually agreeable to both the Cooperative and the Customer. The Cooperative shall maintain the lighting equipment, including lamp replacement, at no additional cost to the Customer within 72 hours after the Customer notifies the Cooperative of the need for maintenance of the lighting equipment. The lighting equipment shall remain the property of the Cooperative. The Customer shall protect the lighting equipment from deliberate damage. The Customer shall allow authorized representatives of the Cooperative to enter upon the Customer's premises and to trim trees and shrubs as necessary for maintenance of the lighting equipment and for removal of the lighting equipment upon termination of service under this schedule. The Cooperative and Customer may execute an agreement for service under this schedule for a period of not less than one (1) year. Should a city, town, or village designate use of metal standards, then the added average cost in place of such units above the average installed cost of a thirty-foot (301) wooden pole will be paid by the Customer. Equipment Rental only Should the Customer have metered electric service available, and it is not convenient for the Cooperative to furnish unmetered service for the outdoor lighting installation, the Cooperative will furnish an outdoor lighting unit to the Customer, except less electricity at these rates: T 175 Watt Mercury Vapor $3.05/month 1. 400 Watt Mercury Vapor $4.SS/month I 100 Watt HP Sodium $3.05/month N 1SO Watt HP Sodium $4.SS/month Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 26 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Each bill for utility service(s); regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. � � r Section Sheet No. SOUTH PLAINS =CTRIC COOPERATIVE, INC. 20 27 Tariff for Electric Service Revision Page 1 SECTION TITLES PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .10 PUBLIC STREET LIGHTING SERVICE Availability Available to incorporated cities, towns and villagesi and the state of Texas, for use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to established rules and regulations. Type of Service Single-phase service at primary or secondary voltage for delivery to street lighting facilities and systems owned and maintained by the agency. Frequency and voltage shall be subject to reasonable variation. Service may be unmetered and kWh will be calculated. Rate Customer Charge: $17.95 per month; plus, Energy Charge: $0.02696 per kWh for all kWh used per month. Minimum !Monthly Charge The minimum monthly charge under the above rate shall be the customer charge plus $1.00 per lighting unit served from the Cooperative's distribution system, but not including any applicable billing adjustments provided under Tariff Section 20.01. Conditions of Service 1. Service will be delivered at the Cooperative's distribution system, with all necessary wiring therefrom to the street lighting system to be furnished and maintained by the Customer. 2. Service delivered hereunder will be used for street and roadway lighting purposes. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLES PUC RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS Billing Adjustments Reference Tariff Section 20.01. Terms of Pavment Section Sheet No. 20 28 Revision Page 1 Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. I ., SOUTH PLAYNS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: I PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS .11 DEMAND SIDE MANAGEMENT (DSM) Availability Section Sheet No. 20 1 29 Revision Page 1 Available to Customers of the Cooperative participating in the Demand -Side Management program and being served under the following rate schedules 1. Irrigation Service Rates DSM Participation Credit The DSM participation credit is: I. Irrigation Service - Summer Season: $0.0375 per kWh for the first 200 kWh/hp of usage during the months of June through August DSM Program The following described the applicable DSM Programs Irrigation Service A. Cooperative will interrupt Customer load only during: 1. Months of June, July, August 2. Days of Monday through Saturday 3. Sours of 12 noon to 10:00 p.m. B. Cooperative will not interrupt Customer load more than a total of 120 hours during the months of June through August. C. Cooperative will interrupt service to all participating Customers at the same time subject to the Terms and Conditions of Service. D. Program participation is limited to 36,500 BP. E. Customers requesting service after June 1 do not quality. F. Program will be effective June 1, 1993. I SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Section Sheet No. 20 30 Revision Page 1 N Terms and Conditions of Service 1. The Customer will executd-a Demand -Side Management Agreement. 2. The Customer will make a contribution -in -aid -of -construction payment equal to 50% of the total cost (including installation labor) of the Demand Management Switch. 3. If the Customer should override or disconnect DSM control during the summer season (June through August) or not comply with the provisions of the Demand Side Management Agreement, the program credits will be terminated; any credits previously received by Customer will be repaid to the Cooperative by Customer and the demand management switch removed. Additionally, Customer will pay the Cooperative any additional wholesale power cost resulting from Cooperative's Inability to control Customer's demand. 4. Cooperative reserves the right to implement the DSM control program and the associated customer service interruption and service restoration in a manner that provides maximum reliability for the entire electric distribution. system. Depending upon system load conditions, it is possible that the service to participating Customers may not be switched on or off at exactly the same time. S. Cooperative is not responsible for any loss or damage associated with DSM Program service interruption. JUN-?43-.9,WED 16 : 53 MLK FAX N0, 512 495 6093 y- Law Offices McGINNIs,. L,GCHRIDGIJ & KILGORE L.L.P. 1300 Capitol Center 919 Congress Avenue Austin, Texas 7EI701 Telephone: (512) 495-P000 Fax No. (512) 495-6093 P. 01 h6�gg1011 �za3��s "- F�0 S ®613 \ c C Confidentiality Notice: The documents accompanying this telecopy transmission contain confidential information which is legally privileged and intended only for the use of the recipient named below. We request immediate notification by telephone of misrouted telecopy transmissions so that we can arrange for return of those documents to us. If you receive this telecopy in error, you are hereby notified that any disclosure, copying, distribution or the taking of any action in reliance on the contents of this telecopied information is strictly prohibited. TELECOPIER TRANSMITTAL. NO. PAGES (include ----r?4— , TO: DON - �iJ�'��C, FAX #: y `- � — / 9 4 FROM: kA�))V),5 MESSAGE: r- , _/ DATE: _4� . �_. _ _ CITY: C-Ty PHONE NO. _806 % PHONE NO."I Please verify pages received, and if any difficulties, Call (512) 495-6000, Ext. 2115 N Priority I (Someone Waiting or For Filing) Priority it - Needed By: Today Completed By: _�/� Dater �� _ Time: 41, JUN-23=930 WED 16 , 53 `` MLK , "`,u FAX NO, 512 495 6003 P. 0� section Sheet No. SOi�L� PLAINS =CTRIC COOPZRATIVE iNC 20 1 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICARLZ TO ALL AREAS TABLE OF CONTENTS SUB -SECTION SUBJECT .01 Billing Adjustments . . . . . . . . . . . . . . . 2 .02 Reeidential Service . . . . . . . . . . . . . 4 .03 Large Power . . . . . . . . . . . 7 .04 Irrigation Service . . . . . . . . 10 .05 General Service 14 .06 Cotton Gin Service . . . . . . . . . . 16 .07 Oil Field Service -Secondary voltage . . . . . . 19 .08 Primary Service voltage . . . . . . . . . 21 .09 outdoor Lighting Service . . . . . . . . 24 .10 Public Street Lighting Service . . . . . 21 .11 Demand Side Management . . . . . . . . . . . . 29 N JUN-23-93 WED 16:54 MLK FAX N0, 512 495 6093 P,03 section Sheet No. SOUTH PLAINS ELECTRIC OOOPLRATIVE , INC. 20 26 Tariff for Electric Service Reviaion Page 1 SECTION TITLE: PUC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Terma of Payment Each bill for utility service(s), regardless of the nature of the aervtce(s), is due upon receipt and delinquent 15 days after issuance unlee® such day fallrs on a holid {y or weekend, in which case payment is due on the next work day. If full payment ie not received in the office of the Cooperative on or before the date such bill is 3La, the customer's account will be considered delinquent and subject to diaco►:ncctton in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. LAW OFFICES LoCHAIDGE & KILGORE, I-L-R 1300 CAPITOL. CENTER 919 CONGRESS AVENUE AUSTIN, TEXAS 78701 _ 601714 3 Mayor and Governing Body City of Lubbock P.O. Box 2000 Lubbock, Texas 79547 I rill - �1r il��l �t ll�r�fllll��lll'Ilrill LAW OFFICES MCG'iwms, T.00HBIDGE & KILGORE, L.L.F. 1300 CAPITOL CENTER 21550 TEXAS COMMERCE TOWER 919 CONGRESS AVENUE 8 300 CHARLES COVRT 600 TRAVIS STREET AUSTIN, TEXAS 7870I 205 NORTH PAESA STREET HOUSTON, TEXAS 770OZ (713) 227-6000 (512) 495-6000 SAN ANTONIO, TEXAS 7a205 (210) 226.1231 FAX (713) 236-a5a5 FAX (512) 495.6093 FAX (210) 226.1019 "TtR'S D.MCCT a11 MW.GEW (512) 495-6046 z1,4324266 ?�� June 21, 1993 Ji�O� 1993 ��Zp21222.�2�,� ^�V �� lP�j.i94Y�••t CJ J 199 is C4iy rti� C j f�,/ CV ��l Ma or and GoverningBody Y City Lubbock a ��r� s c� `�IIIOl6S of P.O. Box 2000 Lubbock, Tx 79547 68L9C')'w Re: Application of South Plains Electric Cooperative, Inc. for Authority to Change Rates; PUC Docket No. 11904 Dear Mayor and Members of Council: You may recall that South Plains Electric Cooperative, Inc. has requested authority from the City of Lubbock to change rates within the City of Lubbock and has requested authority to change rates in all other areas from the Public Utility Commission of Texas. I am pleased to report that the Public Utility Commission has now taken final action approving the Cooperative's request to change rates. A copy of the Commission's final order and approved tariffs is enclosed for your consideration in determining what rates ought to apply in the City of Lubbock. The Cooperative requests that the same rates be approved so that the Cooperative will have uniform system -wide rates in all areas served by the Cooperative. You will note that the Public Utility Commission authorized the Cooperative to implement revised rates effective June 17, 1993. In order to coordinate the implementation of rates inside and outside the City of Lubbock, the Cooperative asks that the City of Lubbock enter an order authorizing the implementation of revised rates effective on and after June 17, 1993. As I understand it, this matter is scheduled for review by the City of Lubbock at 11:00 a.m., June 24, 1993. I am planning to be present at that time to answer any questions you might have, e June 21, 1993 Page 2 however, if questions occur to you earlier, please don't hesitate to give me a call. ECM/lm Enclosure cc: Jim Roberts Jack Moss Don Vandiver Robert Massengale Yours very truly, Cam ell McGinnis DOCKET NO. 11904 �. 14 APPLICATION OF SOUTH PLAINS ELECTRIC :: `� �,, §•;:, :.,. , PUBLIC UTILITY COMMISSION COOPERATIVE, INC., FOR EXPEDITED AUTHORITY TO CHANGE RATES PURSUANT § OF TEXAS TO P.U.C. SUBST. R. 23.23(C) § ORDER In public meeting at its offices in Austin, Texas, the Public Utility Commission of Texas (Commission) finds that this docket was processed by a Hearings Examiner in accordance with applicable statutes and Commission rules. All parties to the docket and the Hearings Examiner recommend approval of the application as modified. law. The Commission ADOPTS the following findings of fact and conclusions of Findings of Fact 1. South Plains Electric Cooperative, Inc., (South Plains or the Cooperative) is a member -owned distribution cooperative providing retail electric service to approximately 30,756 customers in -the West Texas Counties of Crosby, Hale, Hockley, Lubbock, and Lynn and in the Cities of Lubbock, Sanger, Slaton, Abernathy, Shallowater, Lake Ransom Canyon, and Buffalo Springs, Texas. Application and Statement of Intent 2. On April 1, 1993, South Plains filed an application for a rate increase pursuant to P.U.C. SUBST. R. 23.23(c) (the Rule), requesting an increase of $924,053, or 4.51 percent over actual test -year revenues of $20,510,400 for the test year ending September 30, 1992. 3. The Cooperative's Statement of Intent included a cost of service study, proposed revisions of its tariffs, schedules and statements specifying in detail each proposed change, the effect the proposed change was expected to DOCKET NO. 11904 ORDER PAGE 2_ have on the Cooperative's revenues, andtheclasses and numbers of utility customers affected. 4. The Cooperative's last rate increase was approved in Docket No. 69851 Application of South Plains Electric Cooperative, Inc., for Authority to Change Rates, 12 P.U.C. BULL. 730 (February 25, 1987)(mem.). The Cooperative has not changed its rates under P.U.C. SUBST. R. 23.23(c) for at least twelve months, as required by P.U.C. SUBST. R. 23.23(c)(1)(D). The Cooperative filed the instant case because increases in the cost of doing business have caused its present. rate schedules to yield a level of operating revenues insufficient to maintain its financial integrity. Not ice S. South Plains provided notice of its proposed change in rates as follows: a. By timely publishing, prior to the filing of the Statement of Intent, notice of the requested rate increase for four consecutive weeks on March 3, 10, 17, and 24, 1993, in the Lubbock Avalanche -Journal, a newspaper regularly published and generally circulated in the following counties where South Plains provides service: Crosby, Hale, Hockley, Lubbock, and Lynn; b. By delivering a copy of the Statement of Intent to the appropriate officer of each municipality affected by the proposed change; C. By mail or hand delivery to all customers affected by the proposed change; d. By mail to all electric utilities certificated to provide retail service in the Cooperative's service area; and DOCKET NO. 11904 ORDER PAGE 3 e. By service of notice and a copy of the rate filing package upon the Office of Public Utility Counsel (OPC) concurrent with the Cooperative's filing with the Commission. 6. Although the percent revenue increases published in this docket differed slightly from the actual percent revenue increase for the Irrigation Class (6.05 percent published versus 6.73 percent actual) and the lighting Class (7.57 percent published versus 7.63 percent actual), the differences are small and therefore, insignificant for notice purposes. 7. Texas Register notice was not required in this proceeding. 8. No person or entity sought to intervene in this docket. As the parties did not request a hearing on the merits and waived cross-examination, the docket was processed administratively. The Hearings Examiner admitted into evidence South Plains' application with supporting schedules and affidavits, South Plains' letters and affidavits regarding notice, the rate filing package with schedules, the cost of service study, General Counsel's and staff's recommendations and memoranda, and South Plains' response to General Counsel's recommendations, as well as the parties' revised schedules. 9. The rate increase requested by South Plains will become effective upon approval by this Commission, or, if not approved, will be denied under P.U.C. SUBST. R. 23.23(c)(5) on June 17, 1993. This effective date is more than 60 days after the application filing date as required by P.U.C. SUBST. R. 23.23(c)(1)(C). South Plains agreed to extend its proposed effective date of June 1, 1993, to June 17, 1993, to allow adequate time for Commission review of its application and to resolve any disputed issues. If approved, the Cooperative intends to institute the new rates beginning with the first full billing cycle following Commission approval. General Counsel and Staff Recommendation 10. On April 30,,1993, the General Counsel filed a response to South Plains' application and proposed final order, agreeing that the statement of intent and the application conform generally to the requirements of the Rule; DOCKET NO. 11904 ORDER PAGE 4 however, General Counsel urged approval of South Plains' application only after certain modifications, at recommended by Commission staff. 11. The recommended changes are based on adjustments to two categories of test -year expenses and apply only to those tariff schedules in effect on the application filing date. The changes consist of: (1), reduction to legislative advocacy expenses ($1,329) '(2) reduction to advertising, dues, and contributions ($3,492); (3) elimination of the proposed Large Schools and Churches Class; (4) a combination of those classes with the large Power Class and adjustments to the Large Power Class rate design; (5) lowering of the base power cost factor from the:.$0.054208 per kilowatt-hour (kWh) requested to $0.042135 kWh for all rate classes; and (6) normalization of the test -year irrigation usage to account for..: an abnormally wet weather pattern, adding 'approximately $2,080,473 in operating revenues to actual test -year operating revenues of $20,510,400. 12. The Commission staff recommended a $1,329 decrease to South Plains' operating expenses. This adjustment represents payments made to an outside consultant for legislative advocacy services. The staff considered such payments contrary to Commission policy', as stated in P.U.C. SUBST. R. 23.21(b)(2)(A)• 13. , Staff also recommended a $31,492' decrease to South Plains' operating expenses for advertising, dues, and. contributions. This adjustment is reasonable because the total sum of advertising, dues, and contributions is in excess of 0.3 percent of the gross receipts of the utility for services rendered to the public, as limited in PU.C. SUBST. R. 23.21(b). 14. The tariffs, as filed with the Commission, included a proposal that a new class: large Schools and Churches, be :created. The parties agreed that the creation of this new class was outside the limits of P.U.C. SUBST. R. 23.23(c), and that no good cause existed to justify an exception in this docket. 15. The staff eliminated the proposed; large Schools and Churches Class because P.U.C. SUBST. R. 23.23(c) applies to expedited approval of changes in DOCKET NO. 11904 d PAGE 5 existing rates and defines existing rates to include only those tariff schedules of the utility in effect on the application filing date. Therefore, the proposed Large Schools and Churches Class is more properly combined in the Large Power Class. 16. The staff's adjustments to the Large Power Class rate design are reasonable, because customers in this class will have an incentive to minimize peak demand, and low load factor customers in this class will not experience an unreasonably high bill increase under the recommended rates. Adiusted Base Power Cost Factor 17. The staff's recommended adjustment of the base power cost factor from the $0.054208 per kWh requested to $0.042135 per kWh for all rate classes is reasonable, because the lower base power cost factor reflects the portion of purchased power costs included in base rates. 18. South Plains' purchased power expenses have decreased since its last rate case in Docket No. 6985. South Plains' overcollection of power costs has been returned through its monthly power cost recovery, factor (PCRF). A base power cost factor of $0.042135 per kWh for .all rate classes more accurately reflects current test -year data and will permit the recovery by South Plains of purchased power costs. Normalizing Test -Year Irrigation Usage for Weather 19. The test year was a year of abnormally low kWh usage in the irrigation class, due to abnormally wet weather. Actual irrigation usage for the period ending September 30, 1992, was approximately 36,001,843 kwh, reflecting an abnormally wet weather pattern for the test year, and consequently, low usage for South Plains' irrigation customer class. 20. The staff projected irrigation usage of approximately 71,162,025 kWh for the test year, based on normal precipitation using a twenty year historical average. Therefore, a normalized test -year irrigation usage of approximately 70,000,000 kWh is reasonable in this instance to reflect an adjustment for an DOCKET NO. 11904 ORDER PAGE 6 abnormal weather pattern and abnormally low power usage during the test year for the Cooperative's irrigation customer class. 21. Normalization of the test -year irrigation usage results in :an increase in test -year base revenues of approximately $2,080,473, including a corresponding increase of approximately $1,254,736 in purchased power costs. 22. In the test -year, the Irrigation Class relative rate of return was -86.96. At the proposed rates as applied to test -year usage, the relative rate of return would be -1.19; as applied to normalized usage,-0.735. The normalized revenue projection thus shows that the distribution of financial contribution among classes would, in a normalized year, not be unreasonably preferential, prejudicial, or discriminatory, and would be equitable and consistent in application to each class. 23. The method used by the Cooperative to normalize usage data was acceptable. Revenue Requirements 24. The parties agree that the Cooperative's actual test -year revenues for the year ending September 30, 1992, were $20,510,400: Proposed total adjusted test -year revenues for the Cooperative are $21,434,453, reflecting the agreed revenue increase of $924,053 over actual test -year revenues, as shown on revised exhibits SMB-1 and ELM-3, attached. 25. The parties agree that -the Cooperative's total operating revenue (revenue requirement), after normalization of irrigation, is $23,514,926, as reflected on Revised Exhibit ELM-1, attached to this Order. 26. The proposed adjusted test -year operating expenses of $21,731,578, after normalization, includes approximately $14,641,003 in purchased power expenses. 27. The limit on the maximum base revenue increase (exclusive of purchased power costs in base rates) collected from any customer class is 1.5 times the percentage change in system base revenue. DOCKET NO. 11904 ORDER PAGE 7 28. The system average base revenue increase (exclusive of purchased power costs) here is 12.97 percent. The greatest base revenue increase for any one customer class is limited to 19.46 percent (1.5 x 12.97%) for the Residential, Large Power, and Cotton Gin Classes. Net Times Interest Earned Ratio (TIER) 29. The Commission staff utilized the cooperative financial planning model to evaluate South Plains' request for a rate increase in this docket. Based on the staff's analysis, South Plains' net times interest earned ratio (TIER) for the test year ending September 30, 1992, is .88x, which is substantially below the 1991 Texas median of 1.92x. Without the requested rate increase, the TIER ratios projected by the staff model indicate values of .81x, .74x, and .68x for the years ending September 30, 1993, 1994, and 1995, respectively. 30. With the requested rate increase, the TIER ratios projected by the staff model indicate an increase to the values of 1.02x, 1.31x, and 1.23x for the years ending September 30, 1993, 1994, and 1995, respectively. The TIER values with the requested rate increase are below the REA 1.50x minimum to qualify for new loans. The Cooperative's lenders generally recommend a net TIER should be in the range of 2.5 to 3.5. Debt Service Coverage (DSC) ti 31. The Cooperative's debt service coverage ratio (DSC) for the test year ending September 30, 1992 is 1.27x, which is substantially below the 1991 Texas median of 1.92x. Without the requested rate increase, the staff model indicates that the DSC ratios will decrease to the values of 1.21x, 1.13x, and 1.05x for the years ending September 30, 1993, 1994, and 1995, respectively. 32. With the requested rate relief, the staff model projects DSC ratios will increase to 1.35x, 1.52x, and 1.43x for the years ending September) 30, 1993, 1994, and 1995, respectively. The increased DSC ratio values, with the DOCKET NO. 11904 ORDER PAGE 8 requested rate relief, are above the minimum DSC of 1.25x required by the REA to avoid default by the Cooperative. Equity Ratio 33. South Plains' equity ratio, as a percent of total assets for the test year ending September 30, 1992, is 33.18 percent, which is below the 1991 Texas median of 36.34 percent. Without the requested rate increase, the staff model projects equity ratio values of 29.07, 26.85, and 24.64 percent for the years ending September 30, 1993, 1994, and 1995, respectively. 34. With the requested rate increase, the staff model projects equity ratio values of 29.71, 29.15, and 28.23 percent for the years ending September 30, 1993, 1994, and 1995, respectively. With the requested rate increase, South Plains' equity ratio will decrease at a slower rate than it would without a rate increase. Capital Credit Retirements 35. Because the Cooperative's equity ratio is less than 40 percent, the mortgage agreement between 'the Cooperative and the REA and CFC restricts capital credit retirements to an amount not to exceed 25 percent of margins for the previous year. For modeling purposes, the staff assumed that capital credit retirements will equal 25 percent of previous year margins. 36. Assuming the Cooperative• receives the requested rate increase and achieves projected financial parameters, the Cooperative plans to rotate twenty-five percent (25%) of prior years' net margins in each of the next three years, from 1993 through 1995. General Funds Ratio 37. South Plains' general funds ratio as a percentage of total utility plant was 2.51 percent for the test year ending September 30, 1992. For modeling purposes, the staff assumed a 7.00 percent ratio of general funds as a DOCKET NO. 11904 ORDER PAGE 9 percentage of total utility plant, which approximated the 1991 Texas median of 7.62 percent. An adequate general funds level is more critical for a Cooperative with relatively low interest coverage. Rate of Return 38. South Plains' requested rate of return, adjusted for weather normalization, is 4.64 percent. Although the staff normalized the test year to account for abnormally wet weather, the amount of the revenue increase was not changed as a result of this normalization. South Plains' prospective financial condition with normalized revenues indicates that a 4.64 percent rate of return will improve the financial integrity of the Cooperative in the near term and allow debt service obligations to continue to be met. (SM Revised Exhibit ELM-1) 39. The Cooperative's total invested capital (rate base) is $38,395,432. A return of $1,783,348 corresponds to a 4.64 percent rate of return. (Le e Revised Exhibit ELM-1) 6ttached Schedules 40. The allocation of revenues by customer class is shown on the attached Schedule SMB-I. The revenue increase for the residential class is 5.78 percent. 41. The attached customer billing analyses, shown on attached Schedules SMB-2 and SMB-3, reflect the rate changes per kWh of use for the Residential Customer Class. Page 6 of Schedule SMB-2 has been revised to reflect -a fifty - cent credit for the 'Over 50 Lights' Class of the Lighting Rate Class. Schedule SMB-3 remains accurate after the weather normalization changes and shows a comparison of existing monthly bills with the proposed monthly bills to be experienced by South Plains' residential customers using 500, 1,000, and 1,500 kWh. DOCKET NO. 11904 ORDER 42. The proposed tariffs attached to the original revision(s), pursuant to the Cooperative's and the reflect accurately the changes set forth in this Order. Conclusions of law PAGE 10 application required a staff's adjustments to 1. The Cooperative is a public utility as defined in Section 3(c)(1) of the Public Utility Regulatory Act (PURA), Tex. Rev., Civ. Stat. Ann. art. 1446c (Vernon Supp. 1993). 2. The Commission has jurisdiction over this docket pursuant to Sections 16(a), 17, 37, and 43(a) of PURA. 3. This case was processed in accordance with the requirements of PURA and the Administrative Procedure and Texas Register Act (APTRA), Tex. Rev. Civ. Stat. Ann. art. 6252-13a (Vernon Supp. 1993). 4. As a cooperatively -owned electric distribution utility, the Cooperative is entitled to use P.U.C. SUBST. R. 23.23(c) and has met the procedural and substantive requirements of that rule, '... 5. The Cooperative provided notice in- compliance with P.U.C. SUBST. R. 23.23(c). 6. The Cooperative has met its burden of proof as required under P.U.C. SUBST. R. 23.23(c) and Section 40 of PURA.; 7. In determining whether a proposed revenue increase falls under the 5 percent cap set by P.U.C. SUBST. R. 2323(c)(1)(A), the appropriate method is to calculate the revenue by applying the proposed rate changes to the historical test year data. 8. The proposed rate increase is in compliance with P.U.C. SUBST. R. 23.23(c) because: (1) it is less than the maximum five percent increase allowed by P.U.C. SUBST. R. 23.23(c)(1)(A), on an unadjusted basis, and (2) the percentage change in the base revenues collected from any customer class DOCKET NO. 11904 ORDER. PAGE 11 does not exceed 1.5 times the percentage change in system base revenues permitted under P.U.C. SUBST. R. 23.23(c)(1)(B). 9. The application, as modified by General Counsel and staff, and as agreed to by the Cooperative, is in compliance with PURA and applicable regulations. 10. The rates as modified by General Counsel Cooperative are just and reasonable, are prejudicial or discriminatory, but rather consistent in application to each class of Section 38. and staff, and agreed to by the lot unreasonably preferential, re sufficient, equitable, and .ustomers, as required by PURA In accordance with these findings of fact and conclusions of law, the Commission issues the following Orders 1. The application of South Plains Electric Cooperative, Inc., is hereby APPROVED, as modified by the recommendations of General Counsel and staff, and as agreed to by all parties. 2. The tariff sheets recommended for approval by the General Counsel are approved effective on the date of this Order. 3. The approved rates SHALL be charged for service rendered in the areas in which the Commission is exercising original jurisdiction. Said rates SHALL be charged only for services rendered based on the revised approved tariffs. 4. The resolution of this docket resulted from negotiation and compromise between the parties. The entry of an order consistent with the recommendations and agreements in this docket does not indicate the Commission's endorsement or approval of any principle or methodology that may underlie the recommendations or agreements. Neither should the entry of an order consistent with the agreement be regarded as a binding holding or precedent as to the appropriateness of any principle or methodology underlying the recommendations or agreements. DOCKET NO. 11904 ORDER PAGE 12 5. All motions, requests for entry of specific findings of fact and conclusions of law, and any other requests for general or specific relief, if not expressly granted herein, are hereby DENIED for want of merit. SIGNED AT AUSTIN, TEXAS this Z7 A day of 1993. PUBLIC UTILITY COMMISSION OF TEXAS MARTA ATTEST: HN RENFROti SECRETARY OF THE SSION . REVISED I , tDcwarr Ez�—r SOUTH PLAINS ELECTRIC COOPE9ArM. M. STATEMENT OF MOLC YEAR ENDED SS WASER 30,1992 AcbW Annualhe Pmposad Test Yoar tn�� tn� Tact Y"r OpE ATING REVENUES: Base femme i 24AMM S 924.OS3 $ 2.080.473 S 27,a73.948 PCRF Revenue (4.488,127) (4.488.127) OtherRorronue .____ t�T.?a4 �._._.. .,, ...., 177704 Total Opemting Revenues S 20,510.400 =_92,4_00 $. 080,473 S 23_ ,514" 1 1 OPERATING EXPENSES: PuBleed Power t 18,388,267 S S 1.2S4.736 S 14.641,003 Trsr gmbsbn 2= zm DtstrUuution — Cperatiorl 850.314 860,214 Otabbr son — Malrdervwm 1.015.166 1.015.186 CnreunwrAcoourft 880,T68 e%7d8 Cuatomor SorAca and W-0=e 0rW 12ZO10 ' 122.010 pc nln and Genera! 1XMA14 (4,821) 1a73AN Deprociatfon 1,784,182 1,784.182 Tams 621A83 621.283 *tmr interest & Doductons GIAS4 �,..._.... ,...._,_._ .� 81, ?54 TomtOpamUn4Emoram i 20.481.653 $ 4821 �5,2S4.7W S 21.73 Am OPERAMNO MARGINS — Odom Fixed Charges ; 28,737 S 926,874 $ - 82s.7S7 S 10"89" FDaM CHARGES: uftmst on Long Term Debt $.929, s� . ice_ .8 t OPE7AAMNG MARGINS - After Fbmd CtraMes 8 (1.Sa6194 $ OM874 $ 825.737 s _,954.929. 428,419 cruet Non—Opomgng IM mons cXm1 cApilst Credits NET OPERATING MARGINS NONOPERAMNG MARGIN !castes! and Invodntent Mcomo NET MARGINS (LOSS) TIER Not Mcci fled Operating RATE BASE datum on Rate Barn as" (15.167) (i%im 1T..,.4.T81 ... T s~ ' a s 8„29.674 $:::-3— se�ass 6_ �169.702 S� S_..==aWM _.,.� 1174 #.CZ737 _.....=�JSS 0.26 Ise 0.14 1.43 0.02 1.3,2 $:38 3KI81 S38,.VS.492 amm 4AM ..- ... %. CA !%C Public UdUty Commission olTe w South Phial Electric Cooperative. lna Dodd No.11904 St:WUIG SMB-1 Ad usted Test Ytu pre Test Year Base Rev. Power Cost Staff Base Rev. Percent Pcacent Customer kWh Ebacluding Rcvcaue is PCRF Total PWposod BwL Pawn Hasa Rev Tout ToW Rev CIM Saks Power Coats Use Rates Revenue Reveaua Increase Costs Increase Revenue Increase (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) R+esidentW 149."= 2r6S7,443 4293,688 0 AX1.131 517.138 3,174,%l 19.46% 9AWO 5.78% Irrigation 34001AC 1.229.9W 1.516$21 0 2.746„830 184A27 2,414,735 MW% 2931AS7 6.73% General Service 27.037.006 722.114 9=19 0 IAVA33 0 72Z.114 0. M 1,6SOAU 0.W* Lugo Power 44M.266 9StS,.756 1.97SAW 0 Z971XA MAN 1,156,237 160DA 3.13t IW 537% Cotton Guts 12,",W 9050 =.Ml 0 &V.041 19,450 119,4W 19.46% 654,491 3Z% Oilbdd Secondary 37,074,314 1^8,487 1,%ZIIO 0 2,b3Q,597 0 IA4487 OM 2AW97 0= Oilfield Primary 69".091 A433 281,336 0 30.769 61311 38.744 19.4M 320.= 2.01% Ughting 6.9 O53 189,338 293,533 0 482,871 xW 226.184 19L40* 519,716 7.63% Other Raveftue 127,704 127,704 127,704 OM% 127,704 OMX Total 317,702.856 7.I24.133 13,386.2d7 0 2gSIOA00 924.W3 SM4186 21.434AS3 4.5196 Swdm 23Z(cxfxA) YOU Penn&Clasp to roof Rome" 431% sesuoa 2313(exfxs)T.et PraxaLap Ckeaga 14 Sresu lb" Rewswe - SMADIST W.W + l2x% is Uaw pa�oesuaaaL�p V roman bw wMea� • 32.4776 a f.>; - 19A67L Srrr Dar lWW4" CMt (WC) - Tier poor kWk / Ta1 Yat r"***r Cow - -3FI.MA s113J66.UT - waius a<wa Mae.: (1) Frea CooesPA ibir EW—S (6) "boa (rt)aeoba.a (i) (2) Cob as (S) — Corms (3) (1) oobna M +OAUW (6) (3) tobas (1)a Saff BP'C (a) Ks bySAU (4) Sol KRF to am (9) eobaa 0) + sofaau (6) (f) Fee. Caoo'. FAMW UJA-S Va) ("ban (4) -*alms ())/taboo 0) N S 19 _ dautl�PWas ElaaMoQoo�pON.lnor Sao Exilluram-3 Twt VOW 8a TW Year Pa"ma i�-•rsaIn T PCRYF� t POW1}!b! PT ot�d 1G Qw�pa � T3 cum Qmmmm py�iK.c t.o,� li8!!�!# YlMLL 1er:..as ftMGSt! M i - w PM WENML 14.120 /9.01.704 i2A37AQ {0.*1.400 so =B, lim "17.1" 90.40.= wis OiNOMM 8.444 "Act" IAM.M IANA, I 0 2. "AW . 164.W I0614.730 Mw% f.1<alAP an% GENERALG RM fjo ZZA,RJM ZZZ114 OZ4010 0 104=1 0 722.114 CA09L I.t60A3 OAO'Ifi w" POW10I 130 4t t7Q.961 0947i0 1.9 5j= 0 ? 0 IAU Iss'"I 1.1i0.Zi7 164" 6.1SUM 6W% =O11GOJs 10 liAY0.600, 03.040 6iL1001 0 i36.0/1 10.4iD 110.40D iQANt 9"1 &"s ,tp pLi1EW 014J1AilY W , 57.474.SH 1ABi.4i7 1.M1/D 0 2AN07 0 1.D{O.N7 0A0li W407 0AM *u;mLDPii "wf !1 tA77.001 42.4N 261.W0 0 MSIM 4f11 W44 10A t 320.000 Lot'S UQHnN0 GAM Oil"A 3 148.330 914AU 0 40IA11 "AO Um" f0AM 64t1710 Ms OTHERMEWE IV.M IVJ04 It7.704 O"% IVJ04 L OS TOTALS S _ 017J02M ....M �1� 4.51% U221oX►JW Pwoewtep+ah"*lftfAw asnue i924Mj t+ 1Q D 4,a11� Peraenb90 dmnp be systom baw mom- i9Z4.8611 $7.124.130 12l7b .. Utam pacutawchwvsInavambasaalwww" i?ams 0 w .r m P,ubUc UiAity Commissbn of Tcxss South Ptains Elecut Cooperaik, its Docf d No. 11904 B 1LL 1NG PROPOSED TERMINANTS RATE RES1DENVAL Customer Charge 168A" S6M Energy Cbuge 116.184,233 SOA5817 Subtotal 116.154,233 FACE NEAT — SEPARATE METER Customer Charge 5,747 50.00 Energy Charge Nov —Apr 3,759,574 S0.M03S May —Oct 1993,89r7 $0.05817 Subtotal 5,753,471 $FACE HEAT — SINGLE METER Schedule SP Page 1 of 6 S 1,008.474 S6,7S8.437 $7,%6911 So $114.103 S i IS98S S230A98 Customer Charge 1.251 $6.O0 $7,542 Eacrgy Charge Nov —Apr 1st 500 kWh I.05S.430 WSW S61 j94 Remaining, Mi 716911 SOA3o3S 521,72 May --Oct All kWh 287, M SOZ917 $16,729 Subtotal 2A599?2 ' $107,423 WATER HEATER Custornes Charge 13.718 SUD SWU Energy Charge 1st S00 kWh 6957,135 50.05817 $404 j697 Next $00kWh 5pu,220 So.E3873 S19S,90S Remaining kWh 4.320,220 SO05817 S2SI.307 Subtotal 16,.335975 5934,217 Public Utility Commission or Texas Schealuk SM South PbUs Electric Coopervfhc, toe Page 2'ar6 Docket No.11904 Pcortosed Rite Schedules and Pro Forsna Rewrives CUSTOMER CLASS BfLLM DETERMINANTS PROPOSED RATE REVE.%IW SPACE HEAT — WATER HEATERI SPACE HEATER Customer Cbarge 4,821 S6.00 S28,M F.aergy Cbarge Nov —Apr 1st S00 kWh 1;031,231 $0.05817 $62,895 Next S00 k" 1.115,189 SO.03873 543,191 Remaining kWh 3,010,592 $01 03S $91pi May —Oct 1st 500 kWb 1,320.121 $0.05817 576,791 Next 500M 1,011,3W SO.038'73 $39,168 Remaining kWh 1.499,569 $0.05817 587= Subtotal 9AM.002 $429,573 'DOTAL RESIDENTIAL $9,468,212 0 Public UtsMY CoaimissiOO of runs South Ptairs Vedic Cooperatbc, ioc. Docket No.11904 Noposc.d Rate Schedules and Pro forma Rewnues Schedule SMB-2 Page 3 of 6 B1LLINO PROPOSED CUSTOMERCL SS DETERMiNANiS RATE REVENUES MIGAMON *tON—CONTROLI„ED Tout BOB 4734$ Energy Charge July —Sept list 200 kWh per HP 7399,WS $0.1241S $943.421 Remaining LAI 7,701,201 $0.05618 S509AS Oct —June All kWh S;M.623 SOA5924 S308.08S Annual Minimums Subtotal 500, 20.869 S1SSS970 ,817,142 COBOL ANY77ME Total Buts 15,%2 Energy Charge Jul list 200 kWh per HP 4p7.166 S0.1241S 5606,742 Remaining kWh SOM618 $304;88 Oct —June All kWh <.?98 30 SOA5924 $?, ;S3 Annual Minimums 311.143 Load Management Credit 4387,166 (SOA375o) ($183.269 Subtotal 14 S1.6Q3,157 CONTROL 3 DAYS i WEEK Total Bms 647 ' Energy Charge J*lst �t kWh per HP 111325 $0.1241S $13321 Remaining kWh losi6tS $0.06619 $7,188 Oct —June All kWh 131bW SOAS924 $7XO Annual Minimums $834 Load Management Credit 11132S ($0.037S0) ($4,17 Subtotal 351 AM S2S,468 Total Bab Energy Charge July —Sept list 2W kWh per HP 202p10 S0.1241S $25A80 Remaining kWh 2403Si SOM618 S1S920 Otx—June Ail k1�'h 124349 SO.=4 57,366 Annual Minimums six$ Lead Wanagement Credits 202p10 ($0.M750) {S7x Subtotal S66 10 S4 718 V c UtAityCommissioeotTuzs PUim Electric Coop�erathe, foe. , No.11504 �d Rate Schedules and Pro Fon rntr'r'gpl,1 DAYS /WEEK foul BMS Energy Chute July —Sept 1st 200 kWh per HP Remaining kWh Oct —June All kWh Annual Minimums ,Load Management Credits Subtotal TOTAL IRRIGATION GENERAL MVVICE Customer Charge f nergy Charge Qeneral Use Space Heat Nov —Apr May —Ott Tote BfLLfNG 139,574 96,396 63,100 139,574 299A70 19�12 21.34972 47,752 S4.U2 22,037.006 Schedule SMS Page 4 of PROPOSED $0.12415 $17,128 $0.05618 $6,379 $0.05924 S3,738 $938 (SO.03750) (SS,234' $23,150 $2,931,635 S 17M S350,240 SOM908 S1,295.918 $0.02660 $1,270 SOZ908 S3,W7 SWAM LARGE POWER Customer Charge IAW S50D0 $92AW Demand Charge 164,797 S8A0 S1,318,376 Energy Chute 1st US kWh / kW 2SA97,786 S0.04M $1.167.047 Remaining kWh 21�S,4480 SOA2622 Tou! S3SS63,440 Public Ut6;ty CotmmWion of Tcus SchedulcSMB-2 Soutb Plain Electric Cooperathe, loc. Page S of 6 Docket No.11904 Pro ed Rate Schedules and Pro Forma Rc%cnues BILLINQ PROPOSED CUSTOMERCL.AS.S DETERMINANTS RATE RFV'E.M" COM. N GINS Customer Charge 231 S5040 Sligo Demand Charge (Apr —Sept) 2,170 $8.00 $17.360 Energy Charge Apr --Sept AD M 233590 SOM313 S7,739 Oct -MU 1st 1MMIkW 4.341,266 $0.07604 $330.110 Remaining kWh 8,124,724 SOM541 $287fi96 Total ! 2,699M $654,4SS OFLFIRI.D—SECONDAR Total BBB 10,758 Hompower Charge 23IA91 S6.00 S1'V9,S46 Energy Charge 37J 7014 $0.03349 SWI,248 Total 37,074,314 $2 f30,794 OIL.MELD — PRIMARY Customer Chuge 256 $50D0 512,800 Demand Charge 1SX8 $7.75 S123,520 Energy Chuge Q577.091 ' SO M752 $183,7S4 Toul 6.677.091 S320,073 Public UlAity Commission of Tcus Schedule SMB-2 South Plains Electric Cooperatf%e, ioc. Page 6 of Dockct No. 11904 Prog2scd Rate Scbcduks and Pro Forma Revenues REVISED BULTNG LIGHTING Public Street Lights Custorner Charge Energy Charge Outdoor Lighting 100 Wait High Pressure Sodium 175 Watt Mercury Vapor 150 Witt High Pressure Sodium 400 Watt Mercury Vapor 17S Watt Halide 400 Watt Halide 1000 Watt Halide Multiple Unit Discount: 21-50 Lights Multiple Unit Discount: Over 50 Lights Equipment Rectal — 6,000 Lumens Equipment Rental —12M Lumens Total TOTAL PRO FORMA BASE RATE REVENUES OTHER REVENUE TOTAL PRO FORMA REVENUES PROPOSED REVENUE REQUIREMENT 36 371a89 18,862 $6,587 1I09 5,727 PROPOSED $1795 $0.02696 $545 $5.85 $8.48 $8.48 ZAS $8M $1750 (SOS ($0 UK) Sb46 S 10A07 $110,343 $331,M4 S16a88 548,W 52,528 $519,312 S21,3W29 $127,704 $21.434.233 S21r434,453 Public Utility Commission of Texas Memorandum TO: Michael Etchison, General Counsel FROM: Stephen M. BenensonAlectric DATE: May 14, 1993 SUBJ: Response to Examinees Order No. 3, Docket No. 11904, Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates This memorandum responds to a request in Examinees Order No. 3 for revisions to Schedules SMB-1 through SMB-3, in light of a corrected Staff memorandum filed by General Counsel on May 10, 1993. There arenorevisions to the above mentioned schedules due to this corrected memorandum. The corrected memorandum from Staff analyst Roland Kinney reflects changes to the rate of return for the Cooperative due to normalized irrigation usage. Schedules SMB-1 through SMB-3 already reflect this normalization. As stated in the corrected memorandum, Mr. Kinney recommends approval of the requested rate increase of $924,053. Since Schedules SMB-1 through SMB-3 are based on this same total revenue increase, this corrected memorandum does not change these schedules as filed. However, the Cooperative has advised me of an error in the proposed Lighting rates in Schedule SMB-2. page 6 of this schedule lists a proposed credit for "Over 50 Lights" of 25 cents. This should be a credit of 50 cents. Since no customer received this credit during the test year, total revenues are not affected. I have attached a revised page 6 of Schedule SMB-2 to this memorandum. ' Pvblic UtUly Commbsloa of Tcus Schcdulc SMB-3 Soutb Plains ElWrk Cooperatk, Toe Docict No.11904 RcsMntial Bil Comparisons Residential aam kWb us a a I Ej&fng Bi0 I Proposed Bal Tacrrcase S laaease % Residential — Regular Rite 500 $3336 MD9 SIX 5.19% 1 AM $60.71 SM.17 53.46 5.70% 1's00 $88D7 $9326 SS.19 5M% Space Heat — Separate Meter Nov — Apr 500 SUA2 $15.18 $1.75 132M 1,Om 52684 S303S $351 13ri% 1x $ 026 S4533 SS26 13.07% May — Oct S00 $2736 S29D9 $1.73 6.32% 11000 SS4.71 SS8.17 $3.46 632% 1x "m $8726 S5.19 632% Space Heat — SEA& Meter Nov — Apt 500 53336 SUM $1.73 5.18% 1,000 M78 $5026 53.48 7 A5% Ix SW20' S6SA4 S524 8.70% May — Oct 500 53336 S3SD9 $1.73 5.18% 1,000 $60.71 SM17 $3.46 5.70';G 1,500 $88D7 $9326. 55.19 SM% Water Heater 500 $3336 S35D9 $1.73 5.18% 1 ipm $5098 SMA5 $3 A7 621% lsoo $7833 S8354 SS2D 641% Space Heat — Water Neater /Space Heater Nov — Apr S00 $3336 S3SD9 $1.73 'Sag% 1,000 55098 WAS $3.47 6mm 1x $MA0 369163 S5.22 8.11% May — Oct 500 $3336 S35D9 51.73 5.18% lim $5098 S54AS 53.47 62M 1 $7834 S8354 SS2D 6.63% u ti LAW orrIcis MCGIwms, LOCHEIDGE & KILGORE, LLP 3 too GARJTOI CENTER 2850 TEXAS COMMERCE TOWER 919 CONGRESS AVENUE 0 300 CKAR69S COURT 600 TRAVIS STREET 'vrV ^' :o�NORTM PRESA :TREE? �USZ'IN. TEXAS l8701 MOUSTON. TEXAS 77002 Z%1N -AliTONIO. TOrAS 11020E (713) 227•6000 (514 495.6000 r'•. l0 2s1 (2 ) 22e•1 rAX (783) 138.0583 rAx (512) 495.6093 � �'. _ - -*AX (210) 22t3•10t9 WINT10•. so= tw. M,wuc (512) 495-6046 June 11, 1993 Mr. Clay Harris Hearings Examiner Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Mr. Harris: This letter is in response to your request for corrections to the proposed order in the above -captioned proceeding. The Cooperative's proposed corrections are as follows: Finding of Fact 19. For the period ending September 30, 1992, irrigation usage was 36,001,043 kWh rather than 38,8740,730 kWh as stated in this finding. It appears that the kWh stated in finding 19 relates to the calendar year 1992. Ordering Paragraph 2 (page 11 of the proposed order). This provision sets up a tariff review process after the Commission's final order. This process is not necessary because the staff has already reviewed and approved the Cooperative's revised tariffs. A copy of the staffs approval accompanies this letter. Ordering paragraph 2 should be revised to state: The tariff sheets recommended for approval by the general counsel are approved effective on the date of this order. To facilitate this request, I am depositing with the tariff clerk, 6 copies of tariffs that are identical in all respects to the tariffs which were reviewed and recommended for approval by the General Counsel. No changes have been made. 2Z IN Mr. Clay Harris June 11, 1993 Page 2 As I am sure you are aware, the purpose of substantive rule 23.23(c) is to establish a process for expediting electric cooperative rate cases. A tariff review process after the date of the Commission's final order is neither necessary nor consistent with the purpose of this rule. Your assistance in making the corrections indicated above is most deeply appreciated. Yours very truly, Camp ell McGinnis ECM/lm Enclosures cc: General Counsel, PUC Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative 0 E:\8\SPLAISS\S=\SARAS53.LTA DOCKET NO.11904 APPLICATION OF SOUTH PLAIN'S L71LIIY COMMISSION ELECTRIC COOPERATIVE, INC. $ - FOR EXPEDITED AUTHORITY § . f+� = OF TEXAS TO CHANGE RATES PURSUANT TO P.U.C. SUBST. R. 2313(c) § GENERAL COUNSEL'S APPROVAL OF PROPOSED TARIFF SHEETS The General Counsel of the Public Utility Commission of Texas, representing the public interest., recommends approval of the proposed tariff sheets submitted on May 12, 1993, by South Plains Electric Cooperative, Inca The memorandum of Staff witness Stephen M. Benenson memorializing his approval is attached bereto. Respectfully Submitted, Nolan F. Warder" Generall�el -• Bret : Slo " m 7�q Depmy Gneunset Counsel PubUc Utility Commission of Texas 7800 Shoal Creek BIvd., Suite 109W Austin, Texas 78757 (512) 458-0278 MEE/gb R\ME&PL\1190d XM0C Public U ' ' Commission of Texas Memorandum TO: Michael Etchison, General Counsel FROM: Stephen M. Benensons lectric DATE: May 24, 1993 SUBJ: Docket No. 11904, Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates I have reviewed South Plains Electric Cooperativets proposed tariffs filed at the Commission on May 12, 1993. The tariffs are in compliance with Staff's recommendations, and I recommend that they be approved. Lw orsicu MCGIyxis, Loc=DGE & KII.GQBE, t_t..P 1300 GOiTOL CtNTCR SOSO rCa..s CO••-C*CC TOWCR 000 rwwIs sraccr "GUSTO►+. roux 77O02 (tea) ar•a000 Was (713) 234•4sas 919 CONCOCaa .VCNUC aIISTW. TrXAS Tarot (sox) •on •4000 V•s (sW .es•soea d vr• now of .w.sa (512) 495-6046 May ;2, 1993 Mr. Michael Etchison Assistant General Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 s 300 C"^06Cs eowar 80s "O*T ..RCa. STACCT SAN A"ONIC. row Texas (MCI a2e•1931 r s (a,o) ass • 4O10 RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PVC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Mr. Etchison: Enclosed is a draft of rate schedules which have been revised to conform with with the staff recommendations in the above - captioned proceeding. Please request that the staff review the enclosed rate schedules to be sure that there are no errors and advise me of the results of their review. If the tariffs are acceptable, I would like to have them filed as agreed tariffs, in the above -captioned proceeding with the request for implementation upon Commission final order. Thank you for your assistance in this matter. Yours very truly, Campbell McGinnis ECM/lm Enclosures cc: Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative zt%9%SPU"3%" zsaa.= SOUTH PLAINS ELECTRIC COOPERATIVE, MC. Tarif f for Electric Service SECTION TITLE: RATE S MIEC ULES APPLICABLE TO ALL AREAS .01 BILLING ADJUSTMENTS Section Sheet No. 20 1 2 Revision � Page 1 TwePVC I PUBLIC UTILITY COMMISSION OF TEM APPROVED IN17'93ccLfET 1190 CONTRV-TO T A9, 7= CLL:RK The Cooperative shall adjust all bills in accordance with the follaLrinq adjustments if applicable. The Power Cost Recovery Factor (PCRF) shall be applied to each AW8 sold in addition to any monthly minimum, contract minimum, or annual minimum charges and shall not apply toward satisfying any of said minimum charges. Power Cost Recovery Factor (PCRF) The monthly charges shall be increased or decreased on a uniform per KNE basis computed monthly as follows: PCRF a (A-B+C)/DM9 (A-B-C) /KWHs Where: PM - Power Cost Recovery Factor (expressed in $/DM) to be applied to estimated energy sales for the billinq period. A - Total estimated purchased electricity cost from all suppliere including fuel for the billing period. . 8 - Total estimated purchased electricity cost from all suppliers including fuel which are included in the Cooperative base rates. The base power cost is computed as: B a (0) (tea) 0 a Base power cost in S/M sold of $0.042135 for all billing months. C - Adjustment to be applied to the current monthly billing to account for differences in actual purchased electricity costs and actual PM revenues recovered in previous periods. Section Sheet NO. SOOTS PLAINS ELECTRIC COOPBRATIVB, INC. 20 3 h Tarif f for Electric Service Revision Page 1 SECTION TITLE: PUC PUBLIC UTILITY COMIIMMSION OF TEXAS STA" APPROVED RATE SCHEDULES JUM 17 '93 cce cy 11904 CCNTqOL # APPLICABLE TO ALL AREAS TARIFF CLERK ENBs - Total estimated energy sales for billinq period. NOTE: BASE POWER COST . COST OF PURCBAM POWER TOTAL ACTS SALES • 13,386,267 0.04213S 317,702,8S6 0 V Section Sheet No. SOOTS PLAINS ELECTRIC COOPERATIVE, INC. 20 4 Tariff for Electric Service Revision Page 1 SECTION TITLE& PUC PUB, i.P, UTii.lrf % 1MIMIS.1 ys M S STAMP A.t-PROVED RATE SCHEDULES ,lL --I 17 '92d co.i,sr 11904 COiNTr40L I APPLICABLE TO ALL AREAS ?=..—%iFe= C4ERY: .02 RESIDENTIAL SERVICE Availability -' Available to Customers for all farm, shop and home uses, (single family residence or I - unit apartment), including lighting, heating, power and home water supply, subject to established rules and regulations, but not applicable for irrigation or 'seasonal agricultural'procesoLng use. Type of Service . . Single phase and three phase at available secondary voltages. Frequency and voltage shall be subject to reasonable variation. Regular Residential Rate Customer charges $6.00 per month Energy charges $.05817 per kWh Minimum Charge The minimum monthly charge under the above rate shall be $6.00 where 10 KVA or less of transformer capacity is required, but not including any applicable billing adjpstments : provided for under Tariff Section 20.01. For members requiring• more than 10 =A transformer capacity, the minimum monthly charge shall be increased at the rate of f1.00 for each additional RVA or fraction thereof required. Payment of the minimum charge shall entitle the member in all cases to the use of the number of kilowatt hours corresponding to the minimum charge in accordance with the rate. Electric Living Service Space Heater — Separate Meter If the Customer shall elect to have all energy used by such space heating metered separately from other uses, then such separate use will be billed as followst customer Charges $0.00 per month Energy Charges November -April $0.03035 per kWh May -October $0.05817 per kWh R Section Sheet No. SOUTH PLAINS BLECMIC COOPERATIVE INC. 20 S Tariff for Electric Service Revision Page I SECTION TITLE s POC �'LoL.L ' i; i Y :siti+ E r /�i ..P�.J�: D STAMP RATE SCHEDULES 1 IC", 11904 JU11 1 cc:!-. 4 APPLICABLE TO ALL AREAS ►------`_z=r I= =�;K - T Space Heater - Sinale Meter Customer Charges $6.00 per month Energy Charge: - — Bovember-April First SOO kWh $0.05817 per kWh Remaining kWh $0.03035 per kWh May -October All kWh $0.05817 per kWh Water Heater When Customer has in regular use a permanently installed 240 volt, 20 gallons or greater, storage type water heater of not greater than 5.5 kilowatts, individual rated capacity, billing will be as follows Customer Charges $6.00 per month Energy Charge: First 500 kWh SO.OSS17 per kWh Next SOO kith $0.03873 per ksfh Additional kWh SO.05817 per kWh All Electric Space Beat When Customer has in regular use permanently installed space heating equipment of an aggregate rated capacity of S kilowatts or more, excluding bathroom heater,.billing will be as follows: Customer Charges $6.00 per month Energy Charges First $00 kWh $0.05817 per kWh Next SOO kWh $0.03873 per kWh Additional kWh $O.05817 per Wh Space Heat - water Beater/Space Beater When customer has water seating in combination with all -electric space heating, billing will be as follows: Customer Charges $6.00 per month SOUTH PLAINS ZLECTAIC COOPERATIVE, INC. Tarif f for Electric Service Section Sheet No. 20 6 Revision Page 1 SECTION TITLE: PQC PUBUIC UTILITY OW-11;+lSSION OF TEYA.S STAHP RATE SCHEDULES 17 APPLICABLE TO ALL AREAS M-4 CL Energy Charge: November -April First SOO kWh Next SOO kWh Remaining kWh May -October First SOO kith Next SOO kWh Remaining kWh Billing Adjustments Reference Tariff Section 20.01. T•_ f0.OS817 $0.03873 $0.0303S $O.OS817 $0.03873 :0.05811 �/ e Terms of Payment Each bill for utility servics(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Section Sheet No. SOUTH PLAINS ELECTRIC COOPBRATIVB, INC. Tariff 20 7 for Electric Service Revision Page 1 SECTION TITLE: PQC STAMP PU6tIC MIAQCOMMISSION OF TEi RATE SCHEDULES APPLICABLE TO ALL AREAS .03 LARGE POWER SERVICE Availability JUN 17 '93 DocK r 11904 CONTROL # TARIFF CLERK Available for general and industrial service to Customers, including large schools and churches, having capacity in excess of 50 VA for all uses including lighting, heating and power and municipal water pumping, subject to the established rules and regulations; not available for cotton gins, oil well, or irrigation pumping. Type of Service Single-phase and three-phase at available primary or secondary voltages; motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate - r Customer Charge: $50.00 per month; Demand Charges S 8.00 per kW of billing demaad per month; plus, p 8nargy Charge: S 0.04650 per kWh for first 17S KW !� $ 0.02622 for all remaiaing XWh. Power Factor Adjustment The Customer agrees to maintain unity power factor as nearly as practicable., To correct for average power factor lower than ninety-five percent (95%), for Customers if and when the Cooperative deems necessary, an adjustment will be made by increasing measured demand one percent (it) by which the average power factor is less than ninety-five percent (95%) lagging. Minimum Konthlp Charge The minimum monthly charge shall be the Wiest one of the following charges as determined for the Customer in question, but not including any applicable billing BOOTH PLAINS ELECTRIC COOPERATIVE, INC. Tarif f for Electric Service SECTION TITLES i PVC ]] RATE SCHEDULES STAMP APPLICABLE TO ALL AREAS adjustments provided for under Tariff Section 20.01. Section Sheet No. 20 8 Revision Page 1 51.fe 1 h 1 / .1 Lmkb APPROVED JUG! 1.7 '93 DOCKET 11904 CONTROL O TARIFF CLERK 1. The minimum monthly change specified in the contract for service. 2. A charge of $1.00 per KVA of installed transformer capacity. Determination of 8111ing Demand The billing demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered, as indicated or recorded by a demand meter and adjusted for power factor as stated above. Conditions of Service 1. Delivery Point - Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. All wiring, pole lines, and other electric equipment (except the Cooperative's metering equipment) on the load side of the metering point shall be owned and maintained by the Customer. 2. Exclusive gas - Service delivered hereunder is for the exclusive use of the Customer and may not be resold.or delivered for the use of others. 3. Metering - when primary metering equipment is used, it shall be located at the delivery point. However, the Cooperative shall have the option of metering at secondary voltage and adding two percent to the metered kilowatt hours to compensate for transformer losses. In the event secondary metering is used, it will be located on the load side of the Customer's transformer structure. Billing Adjustments Reference Tariff Section 20.01. SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Sections Sheet No. SOUTE PLAINS ELECTRIC C OOPER1 %M. INC. 20 9 Tariff for Electric Service Revisions Page 1 Tuc PUBLIC UTIUTYCCOMMISF�SION OF TEXAS JUM 17 '93 ROCKET 11904 CONTRLL ## TARi-F CLERK Each bill for utility service(sF, Fegardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. • 0 SOUTH PLAINS ELECTRIC COOPERhTIVB, INC. Tarif f for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .04 IRRICATION SERVICE RATES Availability Section Sheet No. 20 1 10 Revision Page l PVC PUBLIC UTILITY COMMISSION OF TE M— STA" APPROVED JUN 17 '93 DOCKET 11904 CONTROL* TARIFF CLERK Available to Customers of the Cooperative for service to irrigation pumps and subject to the established rules and regulations of the Cooperative covering this service. Type of Service Single or three—phase, 60 cycles, at standard secondary voltages. The Cooperative may limit the maximum rating of motors where such may cause interference to other Customers. Frequency and voltage shall be subject to reasonable variation. Rate Summer (July through September billing) Energy Charges First 200 kWh per horsepower — $0.12415 per kWh, exclusive of billing adjustments under Tariff Section 20.01, per season. $0.06618 per kWh for all kWh in excess of 200 kWh per horsepower per L season, exclusive of billing adjustments under Tariff Section 20.01. Winter ( October through tune billing) Energy Charges f0.OS924 cents per kWh per season, exclusive of billing adjustments under Tariff Section 20.01. Demand Side Management Eligible customers may receive demand side management. credits in accordance with the Cooperative's Demand Side Management Rate. T 11 Section Sheet No. SOUTH PLAINS ELECTRIC O OPERATIVE, n4c. 20 11 Tariff for Slectric Service revision Page 1 SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Determination of Horsepower PnC STAMP PUBLIC UTILITY CO"AMISSION OF TEXAS APPROVED JUN 17 '93 DO". ET 11904 CONTROL f" q EF CL Pq The horsepower billing purposes shall be the motor manufacturer's Nameplate rating of horsepower output, except that, if the Cooperative so elects, it shall be determined by actual measurements of power input during a period of maximum normal use, less an allowance of ten percent (10%) of input for motor losses. All motors under 5.0 horsepower will be billed at the 5.0 horsepower rate. Annual Minim= Charge The annual minimum charge under the above rate shall be $15.00 per horsepower of connected load but not less than $75.00 and shall be billed at $2.50 per horsepower per month for the billing months of April through September. In the event electric facilities are initially made available for service for only a portion of the year, such annual mini— will be as follows: P a. Service connected in September: b. Service connected in October: C. Service connected in November: d. Service connected in December: Whorsepower, but not less than $30.00 i4/horsepower, but not less than,f20.00 $2/horsepower, but not less than $10.00 so annual minimum Should the total of all monthly billings in a 12 month period be less than the annual minimum charge, the consumer will pay the difference between the total billing exclusive of billing adjustments under Tariff Section 20.01,, and the annual minimum charge specified therein. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service Section Sheet No. 20 1 12 Revision Page 1 SECTION TITLES Pue I PUBLIC UifL:iY COVM11� ;G,46 Cr- 7Uk; STAMP APPROVED RATE SCHEDULES JUN 17 '93 Doc,« 11904 APPLICABLE TO ALL AREAS Standby Irrigation Service CONTROL It TARIFF CLERK To defer or prevent the Cooperative from retirement of an idle irrigation service for a period of one year or less, the Customer may place an irrigation service on standby. The Cooperative will disconnect the service and may remove the meter and transformers for use elsewhere. Idle Service Annual Charges $10.00 per horsepower per year, but not less than SS0.00 nor more than $300.00, billed not later than April 1S each year, plus; Reconnect Fees S2S.00 With a minimum of seventy-two (72) hours notice, the Cooperative will reconnect the facility, so that the Customer may receive electric service under one of the above rates. Should the Customer have the standby service changed to an active service later in the irrigation year, any amounts paid as Idle Service Charges (except Reconnect roe) shall be allowed toward the applicable Annual Minimum Charge above. .Power Factor Adiustment The Customer agrees to maintain unity factor as nearly as practicable. The horsepower for billing purposes will be adjusted for Customers with 50 horsepower or ire to correct the average power factors lower than ninety-five percent (95%), and may be so adjusted for other Customers if and when the Cooperative deems necessary. Such adjustments will be made by increasing the horsepower one percent (1%) by which the average power factor is less than ninety-five percent (M) lagging. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment $ach'biil for utility service(s), regardless of the nature of the ssurvice(s), is due upon SOUTE PLA2NS ZIXCTRIC COOPSRATM, INC. Tarif f for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Section Sheet No. 20 13 Revision Page 1 PUC PUBLIC UTILITY COMMISSION OF TEXAS STA" APPROVED JUN 17 '93 DOCKET 11904 CONTR-OI. 9 TARIFF CLERK receipt and delinquent 16 days alter issuance unless such day falls on a holiday or weekend, La which case payment is due on the next work day. If lull payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03 t SO=H PLAINS EZL'CTRIC OOOPEPATIVE, INC. Tariff ff for Electric Service Section Sheet No. 20 1 14 Revision page 1 i'UdLIC UTlL1 j'Y t;GMDj11SSIGN GF TEXAS SECTION TITLE: STVW APPROVED RATE SCHED=S JUN 17 '93 DOCKET 11904 APPLICABLE TO ALL AREAS .05 GENERAL SERVICE Availability CONTROL 0 TAIRIFF CLERK Available for commercial, industrial, municipal water systems, apaxtment houses, and three-phase service having a capacity of SO M or less, for all uses including lighting, heating and power, subject to the established rules and regulations. Rate is not available for cotton gins, oil wells or irrigation pumping. Type of Service Single-phase and three-phase at available secondary voltages motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charge: $17.95 per month Energy Charges $ 0.05908 for all kWh per month Minimum Monthly Charge The minimum monthly charge under the above rate shall be $17.95 Where 10 M or less of transformer capacity is required, but not including any applicable billing adjustments provided for under Tariff Section 20.01. For Customers requiring more than 10 RYA of transformer capacity, the minimum monthly charge shall be increased by S1.00 for each additional KVA or fraction thereof required. Minimum Annual Charge for Seasonal Service Customer requiring service only during certain seasons not exceeding nine months per year may guarantee a minfm= annual payment of twelve times the minimum monthly charge determined in accordance with the foregoing section, in which case there will be no -+nf=,- monthly charge. IN Section Sheet No. SOOTS PLAINS MSCTRIC 000PSRATIVB, INC. 20 15 Tariff for Electric Service Revision Page 1 SECTION TITLE: RATE SCE=ULES APPLICABLE TO ALL AREAS Space Heating PUC PUBLIC UTILITY COMMISSION O TEXA, STAMP APPROVED JUN 17 '93 voco►car 11904 CONTROL ;# TAR:FF CURK when a Customer regularly uses permanently installed electric heating equipment, 5 KW or more of total capacity in one building and energy for the space heating equipment is measured by a separate meter, all kWh so metered during the November, December, January, February, March and April billing periods will be billed at $0.02660 per kWh subject to the following conditions: 1. The Customer's wiring will provide for a main service meter to measure kWh used for all purposes except space heating and air conditioning compressors, and further provide for a separate meter to measure only energy used exclusively for space heating equipment and air conditioning compressors. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. if full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject ta, disconnection in accordance with the rules of the appropriate regulatory authority. Penalt Reference Tariff Section 30.03. ES SOOTS PLAINS ELECTRIC COOPERATIVE, INC. Tarif f for electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .06 COTTON GIN SERVICE Availability PVC STAMP Suction Sheet No. 20 1 16 Revision I Page 1 i PUBLIC UTILITY COMMISSiON OF IFUS APPROVE© Jifi 17 '93 nocKET 11904 CONTR-O TAP..F F CLERK Available for power service to cotton gins and supplemental uses, and for other seasonal uses, excluding energy for staadby or shared service with another source of electric power (except qualifying facility). Zee of Service Three-phase, 60 hertz, A.C. at Cooperative's available voltages. Service supplied hereunder will be at a single point of delivery and measured through one meter. Frequency and voltage shall be subject to reasonable variation. Rate Monthly Service Availability Charge: $50.00 Summer Season (April through September Billinq): Demand Charge: $8.00 per XK per month plus Energy Charge: $0.03313 per kWh per mouth Winter Season (October through March Billing): Q Energy Charge: first 100 kWh per KW of demand per month $0.07604 per kWh All additional kWh per mouth $0.03541 per kWh SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tarif f for Electric Service SECTION TITLE: POC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Annual Minimum Charge Section Sheet No. 20 1 17 Revision i Page 1 PUBLIC UTILITY C'J IAISSI0=4 Or i►XhS APPRC?VEL) JUN 17 '93 Docma 11904 CONTROL TARIFF CLERK The annual minimum charge under the above rate shall not be less than $6.50 per connected KVA, but not including any applicable billing adjustments provided under Tariff Section 20.01. Should the total of all monthly billings be less than the annual minimum charge, the Customer will be billed for such difference with the March billing of the year. Off -Season Disconnection Customer is encouraged to disconnect the service during the Summer months that the service is not required. However, one temporary reconnect will be made for a period not to exceed 24 hours for motor test, provided the Cooperative is not experiencing a loading peak on the substation furnishing service to the load. Any kWh used will be billed. KW demand will not be billed; the demand register will be reset. Additional temporary reconnects will be made and billed at $25.00. Determination of KW Demand The demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month in which service is rendered hereunder as indicated or recorded by a demand meter adjusted for power factor. Power Factor Adjustments The Customer agrees ta•maintain unity power factor as nearly as practicable. The XW demand will be adjusted for Customers to correct for average power factors lower than ninety-five percent (95t), if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (I%), for each one percent (1%) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adjustments Reference Tariff Section 20.01. SECTION TITLES RATE SCEEDMES APPLICASLE TO ALL AREAS Terms of Pavment Section Sheet No. SOOTS PLAINS ELBCTRIc COOPBRATM, INC. 20 18 Tariff for Electric Service Revision Page 1 PQC PUBLIC UTILITY COMMISSION OF TVAS TW AFFROVM JUN 17 '93 "o KEi .11904 CONTROL # TARIFF CLERK Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days alter issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. 0 Section Sheet No. SOUTH PLAINS ELSCnUC ODOPERATr", INC. 20 IS Tarif f for Electric Service Revision Page I SECTION TITLE 1 PUc PUBLIC UTILITY COMMISSION OF TEXAS BATE scxEavLEs STAMP AFPROVM JUN 17 '93 mcxu ,119 0 4 APPLICABLE TO ALL AREAS CONi9OL # TARIFF CLERK .Ol OIL FIELD SERVICE - SECONDARY VOLTAGE Availability Available to Customers of the Cooperative for service to oil well pumps (well head service) and for other uses directly related to oil production where energy is used exclusively by electric motors and subject to the Cooperative's rules and regulations covering this service. Type of Service Single-phase or three-phase, 60 hertz, at standard secondary voltage. The Cooperative may limit the maximum horsepower rating of motors served with single-phase service where such may cause interference to other Customers. Frequency and voltage shall be subject to reasonable variation. Rate Horsepower Charge: $6.00 per horsepower per month, plus, Energy Charge: $0.03348 per kWh per month. R Determination of Horsepower The horsepower for billing purposes shall be the manufacturer's motor nameplate rating, or at its option, the Cooperative may determine the horsepower by test under conditions of maximum operating load. Power Factor The Customer agrees to maintain unity power factor as nearly as practical. The horsepower for billing purposes will be adjusted to correct for average power factors lower than ninety -live percent (M) if and when the Cooperative doems necessary. Such adjustments Will be made by increasing the horsepower one percent (11) by which the average horsepower is less than ninety-five (M) lagging. SOUTH PLAINS MXCTRIC COOPERATIVE, INC. Tarif f for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Minimum Honthly Charge Section Sheet No. 20 1 20 Revision Page 1 PVC PUBLIC UTILITY CC1 "" .. .::;rd U.': TE�►� STAMP I APPROVED JUN 17 '93 DovuZ 11904 CONTROL TARIFF CLERK The minimum monthly charge under the above rate shall be the horsepower charge and Ln no went shall it be less than $17.95 but not including any applicable billing adjustments provided for under Tariff Section 20.01. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service(s), regardless of the nature of the servLce(s), Le due upon receipt and delinquent 16 days after Lasuance unless such day falls on a holiday or weekend, in which case payment Ls due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. r. 1 SOUTH PLAINS ELBCTR.IC COOPERATTVB, ENC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .08 PRIMARY VOLTAGE SERVICE Availability Section Sheet No. 20 1 21 Revision I Page 1 1� PUBLIC UTILITY COMMISSIM OF TEXAS APPROVED SUI 17 '93 occK1T 11904 CONTROL # TARIFF CLERK Available for oil field pumping or Customer -owned primary distribution systems. Type of Service Three-phase, 60 hertz, at the Cooperative's standard primary distribution voltages. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charges 00.00 per months Demand Charges $7.76 per month KW of billing demand; plus Energy Charges $0.02752 per kWh per mouth R Determination of Billing Demand The billing demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered ; as indicated or recorded by a demand meter and adjusted for power factor as follows power Factor Adjustment The Customer agrees to maintain unity power factor as nearly as practicable. Demand charges will be adjusted for Customers to correct for average power factors lower thaw ninety-five percent (M) if and when the Cooperative deems necsssary. Such adjustments will be made by increasing the measured demand one percent (11) for each one percent (U) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adiustments Refelrence Tariff Section 20.01. SOUTH PLAINS ELECTRIC COOPER xrn, INC. Tariff for Electric Service Section Sheet No. 20 1 22 Revision Page 1 SECTION TITLE: PVC pUBUC UTILITY COMMISSION OF TEXAS STAMP APPROVED RATE SCHEDULESJU"J 17 '93 ccc�;� 11904 APPLICABLE TO ALL AREAS Minimum Monthly Charge CONTROL # TARIFF CLERK The mialmum monthly charge shah be the highest one of the following charges as determined for the Customer in question, but not including any applicable billing adjustments provided for under Tariff Section 20.01. 1. The minimum monthly charge specified in the contract for service. 2. a charge of $1.00 per KVA of installed transformer capacity. Conditions of Service 1. Delivery Point - Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. Ali wiring, pole line, and other electric equipment (except the Cooperative's metering equipment) on the load side of the metering point shall be owned and maintained by the.Customex. 2. Exclusive Vas - Service delivered hereunder is for the exclusive use of the Customer and may not be resold of delivered for the use of others. 3. Metering - When primary metering equipment is used, it shall be located at the delivery point. However, the Cooperative shall have the option of metering at secondary voltage and adding two percent (2%) to the metered kilowatt hours to compensate for transformer losses. In the event secondary catering is used, it will be located on the load side of the Customer's transformer structure. Terms of Payment Each bill for utility sarvice (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in Section Sheet No. SOOTS PIJUNS ELECTRIC COOPERATIVE, XHC. 20 23 Tariff for Electric Service Revision Paqe 1 SECTION TITLE: PQC PUB IC UTILITY COMMISSION C: TrYA:3 STAID APPROVED RATE SCEED=S JUN 17 '93 imcm 11904 APPLICABLE TO ALL AREAS CONTROL # TA�i1Flr CLERK accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. Suction 1 Sheet No. STOUTS PLAINS ELECTRIC COOPERATIVE, Xuc. 20 24 Tariff for Electric Service Revision Page i SECTION TITLE: POC PUBUC UTIUTY COMMISSION ;: I EXAS STAMP AFIPROVED RATE SCHEDULES APPLICABLE TO ALL AREAS .09 OUTDOOR LIGHTING SERVICE Availability JUN 17 '93 DMIET 11904 CONTROL # TARIFF CLERK Available to Customers of the Cooperative, except where prohibited by law or ordinance for dusk to dawn outdoor lighting in close proximity to existing overhead secondary circuits. Also, available to incorporated cities, towns, and villages for delivery and use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to the established rules and regulations of the Cooperative. Tvne of Service Unmetered electric energy to lighting units, furnished, installed and maintained by the Cooperative. Frequency and voltage shall be subject to reasonable variation. Rate Per Light for Month Light mounted and connected to overhead secondary unit. 175 Watt Mercury Vapor S S.8S/month 400 Watt Mercury Vapor $ 8.48/month 100 Watt HP Sodium : S.85/month 150 Watt HP Sodium : 8.48/month 175 Watt Halide : 5.85/month 400 Watt Halide $ 8.52/month 1000 Watt Halide $17.SO/month Multiple USE Discount 21 through SO units: over 50 units: Billing Adjustments =0.25 per unit per month $0.50 per unit per month Reference Tariff Section 20.01. N N N N N Jr Sect ion Sheet No. SOUTH PLAINS ELECTRIC COOPERATM, IFC. 20 25 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC PUBLIC UTILITY CO-IMM1SS10,A OF MAS RATE SCHEDULES STAMP APPROVED JUN 17 '93 VOCK:r 11904 APPLICABLE TO ALL AREAS CONTROL # TAMFF CLERIC Conditions of Service 1. The Cooperative shall 'fu-rnish, install, operate, and maintain the outdoor lighting equipment including lamp, luminaire, bracket attachment and control device on an existing wooden pole of the Cooperative, when one is readily available, electrically connected so that the power for operation of light does not pass through the motor for the customer's other uuage, at a location mutually agreeable to both the Cooperative and the Customer. 2. The Cooperative shall maintain the lighting equipment, including lamp replacement, at no additional cost to the Customer within 72 hours after the Customer notifies the Cooperative of the need for maintenance of the lighting equipment. 3. The lighting equipment shall remain the property of this Cooperative. The Customer shall protect the lighting equipment from deliberate damage. 4. The Customer shall allow authorized representatives of the Cooperative to enter upon the Customer's premises and to trim trees and shrubs as necessary for maintenance of the lighting equipment and for removal of the lighting equipment upon termination of service under this schedule. S. The Cooperative and Customer may execute an agreement for service under this schedule for a period of not less than one (1) year. 6. Should a city, town, or village designate use of metal standards, then the added average cost in place of such units above the average installed cost of a thirty-foot (301) wooden pole will be paid by the Customer. Zquipment Rental Only Should the Customer have metered electric service available, and it is not convenient for the Cooperative to furnish unmetered service for the outdoor lighting installation, the Cooperative will furnish an outdoor lighting unit to the Customer, except less electricity at these rates: 77 17S Watt Mercury Vapor S3.OS/month TL 400 Watt Mercury Vapor S4.85/month y 100 Watt HP Sodium S3.0S/month N ISO Watt SP Sodium $4.85/month /v Section Sheet No. SOUTH PLAINS =C.TRIC COOPERATIVE, INC. 20 27 Tariff for Electric Service Revision Page 1 SECTION TITLE: PVC PUBLIC UTILITY CONI' ISSION OF TEXAM ST APPROVED RATE SCHEDULES JUN 17 '93 noc;�� 11904 CaNTSOL APPLICABLE TO ALL AREAS TARIFF CLERK 0. .10 PUBLIC STREET LIGHTING SERVICE Availability Available to incorporated cities, towns and villages; and the state of Texas, for use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to established rules and regulations. Type of Service Single-phase service at primary or secondary voltage for delivery to street lightinq facilities and systems owned and maintained by the agency. Frequency and voltage shall be subject to reasonable variation. Service may be unmetered and kWh will be calculated. Rate Customer Charge: $17.95 per months plus, Eaergy Charge: $0.02696 per kWh for all kWh used per month. Minimum Monthly Charge The minimum monthly charge under the above rate shall be the customer charge plus $1.00 per lighting unit served from the Cooperative's distribution system, but not including any applicable billing adjustments provided under Tariff Section 20.01. , Conditions of Service 1. Service will be delivered at the Cooperative's distribution system, with all necessary wiring therefrom to the street lighting system to be furnished and maintained by the Customer. 2. Service delivered hereunder will be used for street and roadway lighting purposes. Section Sheet No. SOUTH PLAINS ffi.SCMIC COOPEMATIM INC. 20 28 Taxi f f for Electric Service Revision Page i SECTION TITLE: PUc PUBLIC UTILITY COIMMII;iSiOU Of TEXAS STAMP AP?RO V i_D RATE SCHEDULES JTJ 17 '93 0"umu 11904 APPLICABLE TO ALL AREAS TARIFF CLERK Billing Adjustments Reference Tariff Section 20.01.- Terms of Pavment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If fall payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. SOOTS PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .11 DEMAND SIDE MANAGEMENT (DSM) Availability Section Sheet No. 1 20 1 24 Revision J Page i j PUC STXMp PUBLIC UTILITY COMMISSION OF TM APPROVED Al 17 '93 mioKET 119 0 4 C;;VTF•CL # i AR I F CLERK Available to Customers of the Cooperative participating in the Demand -Side Management program and being served under the following rate schedules 1. Irrigation Service Rates DSM Participation Credit The DSM participation credit is: I. Irrigation Service - Summer Seasons $0.0375 per kWh for the first 200 k*Wbp of usage during the months of Juno through August DSM Program The following described the applicable DSm Programs • Irrigation Service A. Cooperative will interrupt Customer load only during: 1. Months of June, July, August 2. Days of Monday through Saturday 3. Hours of 12 noon to 10:00 p.m. , a. Cooperative will not interrupt Customer load more than a total of 120 hours during the months of June through August. C. Cooperative will interrupt service to all participating Customers at the same time subject to the Terms and Conditions of Service. D. Program participation is limited to 36,500 SP. Z. Customers requesting service after June 1 do not quality. F. Program will be effective Jane 1, 1993. N N SO= PLAINS ELECTRIC COOPERATIVE, INC. Tarif f for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Terms and Conditions of Service Section Sheet No. 20 1 30 Revision Page 1 P���J� UTILITY t;0 ","s 31`01" OF i+ X�, JUl! 17,93 9 0 4 CONTROL 4 ��•-:t+ i`.V:,air.: yt.EiiK 1. The Customer will executg'a Demand -Side Management Agreement. 2. The Customer will make a contribution-in-aidrol-coastruction payment equal to 50% of the total cost (including installation labor) of the Demand Management Switch. 3. If the Customer should override or disconnect DSH control during the summer season (June through August) or not comply with the provisions of the Demand Side Management Agreement, the program credits will be terminated;. any credits previously received by Customer will be repaid to the Cooperative by Customer and the demand management switch removed. Additionally, Customer will pay the Cooperative any additional wholesale power cost resulting from Cooperative's inability to control Customer's demand. a. Cooperative reserves the right to implement the DSH control program and the associated customer service interruption and service restoration in a manner that provides maximum reliability for the entire electric dintribution.system. Depending upon system load conditions, it is possible that the service to participating Customers may not be switched on or off at exactly the same time. S. Cooperative is not responsible for any loss or damage associated with DSM Program service interruption. LAW OFFICES MCGINNIS, LOCHRIDGE & KILGORE, L.L.P. 1300 CAPITOL CENTER 2850 TEXAS COMMERCE TOWER 919 CONGRESS AVENUE 600 TRAVIS STREET AUSTIN, TEXAS 78701 HOUSTON, TEXAS 77002 (713) 227-6000 (512) 495-6000 FAX (713) 238-8585 FAX (512) 495-6093 WRITERS DIRECT DIAL NUMBER. (512) 495-6046 June 21, 1993 Mayor and Governing Body City of Lubbock P.O. Box 2000 Lubbock, Tx 79547 B 300 CHARLES COURT 205 NORTH PRESA STREET SAN ANTONIO, TEXAS 78205 (21 O) 226 - 1231 FAX (210) 226-1019 Re: Application of South Plains Electric Cooperative, Inc. for Authority to Change Rates; PUC Docket No. 11904 Dear Mayor and Members of Council: You may recall that South Plains Electric Cooperative, Inc. has requested authority from the City of Lubbock to change rates within the City of Lubbock and has requested authority to change rates in all other areas from the Public Utility Commission of Texas. I am pleased to report that the Public Utility Commission has now taken final action approving the Cooperative's request to change rates. A copy of the Commission's final order and approved tariffs is enclosed for your consideration in determining what rates ought to apply in the City of Lubbock. The Cooperative requests that the same rates be approved so that the Cooperative will have uniform system -wide rates in all areas served by the Cooperative. You will note that the Public Utility Commission authorized the Cooperative to implement revised rates effective June 17, 1993. In order to coordinate the implementation of rates inside and outside the City of Lubbock, the Cooperative asks that the City of Lubbock enter an order authorizing the implementation of revised rates effective on and after June 17, 1993. As I understand it, this matter is scheduled for review by the City of Lubbock at 11:00 a.m., June 24, 1993. I am planning to be present at that time to answer any questions you might have, June 21, 1993 Page 2 however, if questions occur to you earlier, please don't hesitate to give me a call. Yours very truly, Cam ell McGinnis ECM/lm Enclosure cc: Jim Roberts Jack Moss Don Vandiver Robert Massengale G DOCKET NO. 1I904 �. 1 APPLICATION OF SOUTH PLAINS ELECTRICPUBLIC `UTILITY COMMISSION COOPERATIVE, INC., FOR EXPEDITED § AUTHORITY TO CHANGE RATES PURSUANT § OF TEXAS TO P.U.C. SUBST. R. 23.23(C) § ORDER In public meeting at its offices in Austin, Texas, the Public Utility Commission of Texas (Commission) finds that this docket was processed by a Hearings Examiner in accordance with applicable statutes and Commission rules. All parties to the docket and the Hearings Examiner recommend approval of the application as modified. law. The Commission ADOPTS the following findings of fact and conclusions of Findings of fact 1. South Plains Electric Cooperative, Inc., (South Plains or the Cooperative) is a member -owned distribution cooperative providing retail electric service to approximately 30,7S6 customers in -the West Texas Counties of Crosby, Hale, Hockley, Lubbock, and Lynn and in the Cities of Lubbock, Sanger, Slaton, Abernathy, Shallowater, Lake Ransom Canyon, and Buffalo Springs, Texas. Application and Statement of Intent 2. On April 1, 1993, South Plains filed an application for a rate increase pursuant to P.U.C. SUBST. R. 23.23(c) (the Rule), requesting an increase of $924,053, or 4.51 percent over actual test -year revenues of S20,S10,400 for the test year ending September 30, 1992. 3. The Cooperative's Statement of Intent included a cost of service study, proposed revisions of its tariffs, schedules and statements specifying in detail each proposed change, the effect the proposed change was expected to DOCKET NO. 11904 ORDER PAGE 2 have on the Cooperative's revenues$ and the classes and numbers of utility customers affected. 4. The Cooperative's last rate increase was approved in Docket No. 6985, Application of South Plains Electric Cooperative, Inc., for Authority. to Change Rates, 12 P.U.C. BULL. 730 (February 25, 1987)(mem.). The Cooperative has not changed its rates under P.U.C. SUBST. R. 23.23(c) for at least twelve months, as required by P.U.C. SUBST. R. 23.23(c)(1)(0). The Cooperative filed the instant case because . increases in the cost of doing business have caused its present rate schedules to yield a level of operating revenues insufficient to maintain its financial integrity. Notice S. . South Plains provided notice of its proposed change in rates as follows: a. By timely publishing, prior to the filing of the Statement of Intent, notice of the requested rate increase for four consecutive weeks on March 3, 109 17, and 249 19939 in The Lubbock Avalanche -Journal, a newspaper regularly published and generally circulated in the following counties where South Plains provides service: Crosby, Hale, Hockley, Lubbock, and Lynn; b. By delivering a copy of the Statement of Intent to the appropriate officer of ,each municipality affected by the proposed change; c. By mail or hand delivery to all customers affected by the proposed change; d. By mail to all electric utilities certificated to provide retail service in the Cooperative's service area; and DOCKET NO. 11904 ORDER PAGE 3 e. By service of notice and a copy of the rate filing package upon the Office of Public Utility Counsel (OPC) concurrent with the Cooperative's filing with the Commission. 6. Although the percent revenue increases published in this docket differed slightly from the actual percent revenue increase for.the Irrigation Class (6.05 percent published versus 6.73 percent actual) and the Lighting Class (7.57 percent published versus 7.63 percent actual), the differences are small and therefore, insignificant for notice purposes. 7. Texas Register notice was not required in this proceeding. 8. No person or entity sought to intervene in this docket. As the parties did not request a hearing on the merits and waived cross-examination, the docket was processed administratively. The Hearings Examiner admitted into evidence South Plains' application with supporting schedules and affidavits, South Plains' letters and affidavits regarding notice, the rate filing package with schedules, the cost of service study, General Counsel's and staff's recommendations and memoranda, and South Plains' response to General Counsel's recommendations, as well as the parties' revised schedules. 9. The rate increase requested by South Plains will become effective upon approval by this Commission, or, if not approved, will be denied under P.U.C. SUBST. R. 23.23(c)(5) on June 17, 1993. This effective date is more than 60 days after the application filing date as required by P.U.C. SUBST. R. 23.23(c)(1)(C). South Plains agreed to extend its proposed effective date of June 1, 1993, to June 17, 1993, to allow adequate time for Commission review of its application and to resolve any disputed issues. If approved, the Cooperative intends to institute the new rates beginning with the first full billing cycle following Commission approval. General Counsel and Staff Recommendation 10. On April 30,►1993, the General Counsel filed a response to South Plains' application and proposed final order, agreeing that the statement of intent and the application conform generally to the requirements of the Rule; DOCKET NO. 11904 ORDER PAGE 4 however, General Counsel urged approval of South. Plains' application only after certain modifications, as recommended by Commission staff. 11. The recommended changes are based on adjustments to two categories of test -year expenses and apply only to those tariff schedules in effect on the application filing date. The changes consist of: (1) reduction to legislative advocacy expenses ($1,329); (2)-reduction to advertising, dues, and contributions ($3,492); (3) elimination of the proposed Large Schools and Churches Class; (4) a combination of those classes with the Large Power Class and adjustments to the Large Power Class rate design; (5) lowering of the base power cost factor from the $0.054208 per kilowatt-hour (kWh) requested to $0.042135 kWh for all rate classes; and (6) normalization of the test -year irrigation usage to account for an abnormally wet weather pattern, adding approximately $2,080,473 in operating revenues to actual test -year operating revenues of $20,510,400. 12. The Commission staff recommended a $1,329 decrease to South Plains' operating expenses. This adjustment represents payments made to an outside consultant for legislative advocacy services. The staff considered such payments contrary to Commission policy as stated in P.U.C. SUBST. R. 23.21(b)(2)(A)• 13. Staff also recommended a $3,492 decrease to South Plains' operating expenses for advertising, dues, and contributions. This adjustment is reasonable because the total sum of advertising, dues, and contributions is in excess of 0.3 percent of the gross receipts of the utility for services rendered to the public, as limited in P.U.C. SUBST. R. 23.21(b). 14. The tariffs, as filed with the Commission, included a proposal that a new class: Large Schools and Churches, be created. The parties.agreed that the creation of this new class was outside the limits of P.U.C. SUBST. R. 23.23(c), and that no good cause existed to justify an exception in this docket. 15.The staff eliminated the proposed Large Schools and Churches Class because P.U.C. SUBST. R. 23.23(c) applies to expedited approval of changes in DOCKET NO. 11904 ORDER PAGE 5 existing rates and defines existing rates to include only those tariff schedules of the utility in effect on the application filing date. Therefore, the proposed Large Schools and Churches Class is more properly combined in the Large Power Class. 16. The staff's adjustments to the Large Power Class rate design are reasonable, because customers in this class will have an incentive to minimize peak demand, and low load factor customers in this class will not experience an unreasonably high bill increase under the recommended rates. Adjusted Base Power Cost Factor 17. The staff's recommended adjustment of the base power cost factor from the $0.054208 per kWh requested to $0.042135 per kWh for all rate classes is reasonable, because the lower base power cost factor reflects the portion of purchased power costs included in base rates. 18. South Plains' purchased power expenses have decreased since its last rate case in Docket No. 6985. South Plains' overcollection of power costs has been returned through its monthly power cost recovery factor (PCRF). A base power cost factor of $0.042135 per kWh for .all rate classes more accurately reflects current test -year data and will permit the recovery by South Plains of purchased power costs. Normalizing Test-YearIrrigation- Usage for Weather 19. The test year was a year of abnormally low kWh usage in the irrigation class, due to abnormally wet weather. Actual irrigation usage for the period ending September 30, 1992, was approximately 36,001,843 kWh, reflecting an abnormally wet weather pattern for the test year, and consequently, low usage for South Plains' irrigation customer class. 20. The staff projected irrigation usage of approximately 71,162,025 kWh. for the test year, based on normal precipitation using a twenty year historical average. Therefore, a normalized test -year irrigation usage of approximately 70,000,000 kWh is reasonable in this instance to reflect an adjustment for an DOCKET NO. 11904 ORDER PAGE 6 abnormal weather pattern and abnormally low power usage during the test year for the Cooperative's irrigation customer class. 21. Normalization of the test -year irrigation usage results in an increase in test -year base revenues of approximately $2,080,473, including a corresponding increase of approximately $1,254,736 in purchased power costs. 22. In the test -year, the Irrigation Class relative rate of return was -66.96. At the proposed rates as applied to test -year usage, the relative rate of return would be -1.19; as applied to normalized usage,-0.735. The normalized revenue projection thus shows that the distribution of financial contribution among classes would, in a normalized year, not be unreasonably preferential, prejudicial, or discriminatory, and would be equitable and consistent in application to each class. 23. The method used by the Cooperative to normalize usage data was acceptable. Revenue Requirements 24. The parties agree that the Cooperative's actual test -year revenues for the year ending September 30, 1992, were $20,510,400: Proposed total adjusted test -year revenues for the Cooperative are $21,434,453, reflecting the agreed revenue increase of $924,053 over actual test -year revenues, as shown on revised exhibits SMB-1 and ELM-3, attached. 25. The parties agree that •the Cooperative's total operating revenue (revenue requirement), after normalization of irrigation, is $23,51+4,926, as reflected on Revised Exhibit ELM-1, attached to this Order. 26. The proposed adjusted test -year operating expenses of $21,731,578, after normalization, includes approximately $14,641,003 in purchased power expenses. 27. The limit on the maximum base revenue increase (exclusive of purchased power costs in base rates) collected from any customer class is 1.5 times the percentage change in system base revenue. DOCKET NO. 11904 ORDER PAGE 7 28. The system average base revenue increase (exclusive of purchased power costs) here is 12.97 percent. The greatest base revenue increase for any one customer class is limited to 19.46 percent (1.5 x 12.97%) for the Residential, Large Power, and Cotton Gin Classes. Het Times Interest Earned Ratio (TIER) 29. The Commission staff utilized the cooperative financial planning model to evaluate South Plains' request for a rate increase in this docket. Based on the staff's analysis, South Plains' net times interest earned ratio (TIER) for the test year ending September 30, 1992, is .88x, which is substantially below the 1991 Texas median of 1.92x. Without the requested rate increase, the TIER ratios projected by the staff model indicate values of .81x, .74x, and .68x for the years ending September 30, 1993, 1994, and 1995, respectively. 30. With the requested rate increase, the TIER ratios projected by the staff model indicate an increase to the values of 1.02x, 1.31x, and 1.23x for the years ending September 30, 1993, 1994, and 1995, respectively. The TIER values with the requested rate increase are below the REA 1.50x minimum to qualify for new loans. The Cooperative's lenders generally recommend a net TIER should be in the range of 2.5 to 3.5. Debt Service Coverage MCI 31. The Cooperative's debt service coverage ratio (DSC) for the test year ending September 30, 1992 is 1.27x, which is substantially below the 1991 Texas median of 1.92x. Without the requested rate increase, the staff model indicates that the DSC ratios will decrease to the values of 1.21x, 1.13x, and 1.05x for the years ending September 30, 1993, 1994, and 1995, respectively. 32. With the requested rate relief, the staff model projects DSC ratios will increase to 1.35x, 1.52x, and 1.43x for the years ending September 30, 1993, 1994, and 1995, respectively. The increased DSC ratio values, with the DOCKET NO. 11904 ORDER PAGE 8 requested rate relief, are above the minimum DSC of 1.25x required by the REA to avoid default by the Cooperative. Eguity Ratio 33. South Plains' equity ratio, as a percent of total assets for the test year ending September 30, 1992, is 33.18 percent, which is below the 1991 Texas median of 36.34 percent. Without the requested rate increase, the staff model projects equity ratio values of 29.07, 26:850 and 24.64 percent for the years ending September 30, 1993, 1994, and 1995, respectively. 34. With the requested rate increase, the staff model projects equity ratio values of 29.710 29.15, and 28.23 percent for the years ending September 30, 1993, 1994, and 1995, respectively. With the requested rate increase, South Plains' equity ratio will decrease at a slower rate than it would without a rate increase. Capital Credit Retirements 35. Because the Cooperative's equity ratio is less than 40 percent, the mortgage agreement between the Cooperative and the REA and CFC restricts capital credit retirements to an amount not to exceed 25 percent of margins for the previous year. For modeling purposes, the staff assumed that capital credit retirements will equal 25 percent of previous year margins. 36.' Assuming the Cooperative- receives the requested rate- increase and achieves projected financial parameters, the Cooperative plans to rotate twenty-five percent (25%) of prior years' net margins in each of the next three years, from 1993 through 1996. General Funds Ratio 37. South Plains' general funds ratio as a percentage of total utility plant was 2.51 percent for the test year ending September 30, 1992. For modeling purposes, the staff assumed a 7.00 percent ratio of general funds as a DOCKET NO. 11904 ORDER PAGE 9 percentage of total utility plant, which approximated the 1991 Texas median of 7.62 percent. An adequate general funds level is more critical for a Cooperative with relatively low interest coverage. Mate of Return 38. South Plains' requested rate of return, adjusted for weather normalization, is 4.64 percent. Although the staff normalized the test year to account for abnormally wet weather, the amount of the revenue increase was not changed as a result of this normalization. South Plains' prospective financial condition with normalized revenues indicates that a 4.64 percent rate of return will improve the financial integrity of the Cooperative in the near term and allow debt service obligations to continue to be met. (RI Revised Exhibit ELM-1) 39. The Cooperative's total invested capital (rate base) is $38,395,432. A return of $1,783,348 corresponds to a 4.64 percent rate of return. (See Revised Exhibit ELM-1) Attached Schedules 40. The allocation of revenues by customer class is shown on the attached Schedule SMB-1. The revenue increase for the residential class is 5.78 percent. 41. The attached customer billing analyses, shown on attached Schedules SMB-2 and SMB-3, reflect the rate changes per kWh of use for the Residential Customer Class. Page 6 of Schedule SMB-2 has been revised to reflect'a fifty - cent credit for the "Over 50 Lights' Class of the Lighting Rate Class. Schedule SMB-3 remains accurate after the weather normalization changes and shows a comparison of existing monthly bills with the proposed monthly bills to be experienced by South Plains' residential customers using 500, 1,000, and 1,500 kWh. DOCKET NO. 11904 ORDER PAGE 10 42. The proposed tariffs attached to the original application required a revision(s), pursuant to the Cooperative's 'and the staff's adjustments to reflect accurately the changes set forth in this Order. Conclusions of Law 1. The Cooperative is a public utility as defined in Section 3(c)(1) of the Public Utility Regulatory Act (PURA), Tex. Rev. Civ. Stat. Ann. art. 1446c (Vernon Supp. 1993). 2. The Commission has jurisdiction over this docket pursuant to Sections 16(a), 17, 37, and 43(a) of PURA. 3. This case was processed in accordance with the requirements of PURA and the Administrative Procedure and Texas Register Act (APTRA), Tex. Rev. Civ. Stat. Ann. art. 6252-13a (Vernon Supp. 1993). 4. As a cooperatively -owned electric distribution utility, the Cooperative is entitled to use P.W.C. SUBST. R. 23.23(c) and has met the procedural and substantive requirements of that rule. 5. The Cooperative provided notice 23.23(c). In compliance with P.U.C. SUBST. R. 6. The Cooperative has met its burden of proof as required under P.U.C. SUBST. R. 23.23(c) and Section 40 of PURA. 7. In determining whether a proposed revenue increase falls under the 5 percent cap set by P.U.C. SUBST. R. 23.23(c)(1)(A), the appropriate method is to calculatethe revenue by applying the proposed rate changes to the historical test year data. 8. The proposed rate increase is in compliance with P.W.C. SUBST, R.. 23.23(c) because: (1) it is less than the maximum five percent increase allowed by P.U.C. SUBST. R. 23.23(c)(1)(A), on an unadjusted basis, and (2) the percentage change in the base revenues collected from any customer class DOCKET NO. 11904 ORDER PAGE 11 does not exceed 1.5 times the percentage change in system base revenues permitted under P.U.C. SUSST. R. 23.23(c)(1)(B). , 9. The application, as modified by General Counsel and staff, and as agreed to by the Cooperative, is in compliance with PURA and applicable regulations. 10. The rates as modified by General Counsel and staff, and agreed to by the Cooperative are just and reasonable, are not unreasonably preferential, prejudicial or discriminatory, but rather are sufficient, equitable, and consistent in application to each class of customers, as required by PURA Section 38. In accordance with these findings of fact and conclusions of law, the Commission issues the following Order: 1. The application of South Plains Electric Cooperative, Inc., is hereby APPROVED, as modified by the recommendations of General Counsel and staff, and as agreed to by all parties. 2. The tariff sheets recommended for approval by the General Counsel are approved effective on the date of this Order. 3. The approved rates SHALL be charged for service rendered in the areas in which the Commission is exercising original jurisdiction. Said rates SHALL be charged only for services rendered based on the revised approved tariffs. 4. The resolution of this docket resulted from negotiation and compromise between the parties. The entry of an order consistent with the recommendations and agreements in this docket does not indicate the Commission's endorsement or approval of any principle or methodology that may underlie the recommendations or agreements. Neither should the entry of an order consistent with the agreement be regarded as a binding holding or precedent as to the appropriateness of any principle or methodology underlying the recommendations or agreements. DOCKET NO. 11904 ORDER PAGE 12 S. All motions, requests for entry of specific findings of fact and conclusions of law, and any other requests for general or specific relief, if not expressly granted herein, are hereby DENIED for want of merit. SIGNED AT AUSTIN, TEXAS this /7 Bay of 1993. PUBLIC UTILITY COMMISSION OF TEXAS MARTA EYTOK, COMMISSIONe e OBERT M. GEE, CHAIRMAN ATTEST: h% HN . RENFRON SECRETARY OF THE6ni-S-41SION rj REMISED emarr ELM-1 SOUTH PLAINS EtEC I RIC COOPERATM. INC. STATEMENT OF WCOME YEAR ENDED SEPTEIVISM $0.1992 Actial Annuallm Proposed Tetra Increase_ �� Test Yadr OPERATING REV04UES: Base Ra,renue, i 24$70AM i 924.053 S 2 O,473 3 Z, X3AO PCFiF Ravenue (4AM127) (4.488,127) Other Rovanue _ ..__..�.._ _.._ ,_.1271704 Tout Opomting ReVOnUes i 1 400 f ,,.92R fj . 080,473 = 23,514,928 i 1 OPERATING EXPENSES: Purchased Power Tmrrarnlasbn OUrtnbrrtfon — Operation Otsbbuflon — Mabdenam* CormumarAmounb Customer SaMeo and lydom dlonal A&WhIsbadvo and General 0eproeistlor Tames Oftr Marra do Coductlans Total Operating Eponam OPEAAIwa MARGINS — Wom Fixed Chargos PIS CK4RGES: ltri+ared on long Term Debt OPERATING MARGINS — After Fbmd Charges Other Non --Operating Margins Other CApftal Cram NET OPERATING MAROM NONOPERATiNG MARGINS; tntaras! �d lrtwstmaM tncnmo NET MARGINS (LOSS) TIER Nat Modified Opemang IRATE RASE RaRum on Rate as" OWA4 t i9,388�26J ; 2X5 8b0.314 1.015.16d a30.T88 - 122.010 1j"7=4 (021) 1.784►182 CH.03 SMA _ f _ 20.481.M i+4821 S 1.7S4.736 ; 14A41,OW 2205 8SO,314 1r415.1t36 M7W 122,01a IX/3= 1.784,182 62t.263 �.?36 S 21 1�578 = 29,?37 i 90,474 i • 82S,727 S 1 _ t._ _, S 11464.M S (1=192) $ 828.874 i 825.737 S 420.419 &167) mien 174,731 174,751 .1581 i 9OM874 = m,,_: ; 874 i—!�!7 7S? 736 020 1.0 0.14 1.43 0.02 1.32 64354,161 638,395,432 OBM 4M% z* rn �e 1 Public Udliry Commission olTaw South Plains Electric Cooperative. %. Docket No.11904 St:bodule SMB-1 Ad ustod TestYear ploposed Tat Year Base Rev. Power Cast staff Base Rev. Petaeat Percent Customer kWh Eadudin Revenue la PCRF Total Proposed PmcL Powwes Base Rev Total Total Rev (Lass Saks Power Casts Base Rates Reveaua Revenue Increase Costs Ittcrcaso Revenue Increase (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) Resideattal 149371= Z657.443 6,293r688 0 W401 517JU 3,174,.581 19.46% 9,466,Zb9 5.7896 Issipdan 36.001.943 1=9,909 1516.921 0 2.746AOO UWA 27 4414.735 LSD M 7.931A57 6.73% Carnal Scivice 2ZO377X6 722,114 92019 0 1.65Q6W 0 722,114 QWY, IAW.633 OAM Large Power 46►873.266 996.756 1.975A8 0 Z97IA24 L ASI 1,L%.237 16,0076 3.131,30d 53M Cotton Olas 1Z699.580 99,930 53SA91 0 W,041 19,450 119.400 19.46% 6$4.491 3Z% MUM Secondary 37,074,314 1,068.487 1=10 0 240,597 0 2.068,487 OMA 2.&W97 OaDOXo OiMcld Primary 6.67 PI 3Z433 281.336 0 3M769 6311 39.744 11" 320,pl30 2.01% Ughdq 6,966,50 189'M 293333 0 482,B71 34M 226,.184 19.46% 519.716 7A'iti Other Rcvcnuc 1 177,704 127,704 127,704 OM 1ZJ.704 OM% Total 317.70Z= 7.124.133 13,386.2b7 0 2QS10,400 9UA53 8.044186 21.434,453 431% Mesa UZ(sxtxw) Test J%nseatCbaap V ToW Remove • t92tAsi/t±2o3to.roo - saw. 2�33(ext)(td) Tasty Peioai&V Clasp to Srwn 86at aRaw&** - S924AU IS7.124j" •� t.s USHO pennute smap IN $Pambae nVen" • t2.97%a 1S - Soft 8bw Zlo+ws Cast (9FC) • Tem y..• kV/b l T@sc Yau Paws Cew. • - 3 t7.7MA" I - NOWO: (t) From G&W@Ea►iWiELM-3 (2) CalYaa (S) — coulee p) (3) cols as (t)a Sufi BPC (4) Sat PCitF to new (5) Fwa co $ EA4" Mm—) 431% 12. S 19A6 % t+0o11US / kVvr (6) COUN4 p)neebwa (8) (1) eob N (2) + estasea (6) (a) at by Sam (9) equas 0) • Ooaaa 0) (10) ("has (9) -wear (s))/whin (5) g1s..,. t19wgmf 44L w�u►nat iitJ4ERAL LARQE POWER conow c" CKFMLDSWONaAAY CU ELD IPPA" Y UQ4nMo OTHERiiEaWl TaFALS 2LUMI W dat�ltl PI�e+O llrpdo Coop i10. ' bat a0.10�v2 • off"—$ Tint Yaw Baas TiNYON Moni�Md IONN hwrwr 6aotudup powmCod 1iawh Tody0w PCRi: Ta1Yw ToW PR=W cmnoo PI=W 1Lq+inp� 8w TM Gwom i Me 1 m ., n A 146110 1407t=3 $2As7.4i.7 11UNA s 60 ""list "1701n gru4AN IOAM SIAGUM ems AA" M.O01A" 1?+20.900 $Ata, # 0 ?.7"AW . 164JW 1A14JU ta},C.M 2,"IAA a. AS LNO 27.OJIAX Y&M 14 1130.d10 0 1450 " a 722.114 OA01L 1,60A o.001L tm "JIM.200 QW708 tAfUN 0 Loylo 4 16Q+101 1015yi7 14AM UslaW6 LW% 10 12.tp A". MOM 63l1 1 0 &ggmi 100460 '116j" 10.N1i • ASS SJam a97 87.474.314 1AM487 IA=t1D 0 $d60.1iQ7 a t^667 am% 2ASO497 400% !t 60"Aot OZ,4ia Z IMS 0 olvao 41411 W44 10ASS U0.000 trot% SAM 4A"J43 189Abl MA" a 402AYt W48 a24.ta; 10AM suali ms IVIM 127.104 1=7.704 o s 127.704 am% 1 W 431K «.. a►.i:..........�. .tom t6.. :=. P+wo~ Sh"otitoWtwwK+o SS24JWI tMA10.400 4AM Zl�s(aulll0i Psio.ntq. danQr In srbm bw n��r• i924.ob,71 ;7.tt4.lso ," 12A716 191niMy�aowdap�N+sn4ahs7s44ttawt� 1221%R to 9otal6 Public Utlity Commiukn o(Tczu South PtaEns Elcctit Cooperatbe, lot Docket No. 11904 PrnnescQ Rate Schedutes and Pro Forma Rt RESIDENTIAL Customer Charge Energy Charge Subtotal SPACE NFAT — SEPARATE METER Customer Charge Energy Charge Nov —Apr May —Oct Subtotal SPACE NEAT — SINGLE METER Customer Charge Energy Charge Nov —Apr ist 500 kWb Remaining Mi May —Oct All kWb Subtotal WATER NEATER Customer Charge Energy Charge 1st Sao kWh Next 500 kWh Remalaing kWh Subtotal B nI,TNO 168DW 116.184.233 116.184.233 5.747 3,759,574 1,M $97 5,753.471 1,257 1,02,430 116,911 28791 2.p59= 13,718 6,957.13S 5;OSS.220 4.320,220 16,335,575 PROPOSED $6.00 SO.CSS17 Schedule SM8-2 Pate 1 of 6 I S 1,p08.474 S6,7S8.437 $7.766911 SO.00 So SO.m= $114,103 SO.W17 S115y8S S23o.08S $6M $7.S42 $0.05917 SAM So.0a035 $21,7S8 SOM817 $16a29 S 107.423 S6.OD SWM SOM817 S404.697 So.Q3873 $195.90S SO.M817 SU I V7 S934.217 PvbUc UtAitr Commission of Tczsts Schcduk S%J8-2 Sou%b Mins Elwric Coopenthe, IM Page 2 of Dociel NO.11904 Propmed Rstc Scheduks and Pro Forms Rewnues MUM PROPOSED CUSTOMER CLASS DETERMINANTS RATE REVE.'�'tJFS SPACE HEAT — WATER HEATER/ SPACE HEATER Customer Charge 4,82t S6.OD 528926 Energy Cb rge Naar -Apr 1st SCO kWh IM1,231 $046817 $62$95 Next 500kWh 1,115.189 SO.CM3 543,191 Remaining kWh 3,010,592 $0.03035 S91 j71 May —Oa Ist 500 kWh 1,320,121 $0.05817 $76,791 Ncxt 500 kWh 1,011,3M 50 OM3 S39,168 Remaining kWh 1,499A9 SO.W817 S87,?M Subtotal 9,p38,O02 S429S73 TOTAL RESIDENTIAL $9.468,212 G PvbIk Uta;ty Commis3lon of TCXU Schedule SMB—Z South Plains Electric Cooperatk. Toe Page 3 0i6 Docket No.11904 rfoposed Rate Schedules and Pro FOrma Reticnues BILLTNO PROPOSED CUSTOMERCLASS DETERMINANT'S RATE REYENUM IRRIGATION H0=92NTR9im Total BMs 47,598 F�Dcrgy Charge July -Sept Ist 2W kWh per HP 7399ASS SOANIS $943.421 Remaining k%%% 7,701201 $0.06619 S509AS Oct —June All kWb S,200,623 $0.05924 S30SX S Annual Minimums $55,970 Subtotal 20,5W,869 S 1,817,142 CONTROL ANYTIME Tout Bob 1S.%2 Energy Cbarge July—Septst 2200 kWh per HP 4,U7.166 $01241S 5606,742 Remaining kWb 4.597j88 SOM619 $304M Oct —June All kWb 4.79S23O SOM924 S28 X3 Annual Minimums S11.143 Load Management Credit (SOA3750) Subtotal i4�'166 284 S1S.O2.3.�7 CONTROL 3 DAYS/WEEK Total BMs 647 Energy Charge July—Sept �i kWh per HP 11.3 $0.124$13$21 1 Remaining kWh .6S 18 $7,188 Oct—Juae AD kWb 131 jW SOM924 S7„ O Annual Minimums M Load Management Cruets 111,325 (SO-M75O) ($4.17 Subtotal 3S1f600. CONTROL 2 DAYS I WEEK Total B01s aecgy Charge July—Sept u Ist 2200 kWh per HP 202p10 $0.1241S WPM Remaining kWh 240gl SOM619 S1 m Oct —June All kWh 124,49 SOM924 $7,56 Annual Minimums 5l. " Load Management Credit 202p10 (SOA37SO) (S7,S7 I FSo blic Ut4ity Commission otTexas utb Phis Elcctm Cooperative, Ioecks No.11904 nr".ed A,2le Scheduks and Pro Fon t M PROPOSED Page 4 ot6 CONTROL l OAYS MEEK TotalBills 465 Energy Charge July —Sept tat 2w kWh per HP 139574 $0.12415 $17328 Remaining M 963% S0.05618 $6379 Oa —June An kWh 63,100 S0.05924 $3,738 Annual Minimums $938 L,wd Management Credits 139574 ($0.03750) (SS.B41 Subtotal 299A70 523.150 TOTAL IRRIGATION S2,931.635 GENERAL SERVICE Customer Charge 19,S12 $179S $350,240 Ener yCbarge General Use 21$34MI 50.05908 51.295p8 Spar Heat Nov —Apr 47,7S2 $0.02660 S I;270 May —Oct 54,282 SOAS90'8 $9307 Total 22A37.M6 SIA50j636 LARGEPOWER Customer Charge 1A7 $50.00 S82AS0 Demand Charge 164,797 S8.00 $1319376 Energy Charge 1st 17S kWh / W 2SA97.786 S0.04650 $1.167.047 Remaining kWh 21,477,480 SOMC-22 SS63,140 Total 4b37S.266 $3,131.413 u—bue Utdity Commission of Tens Sovib Plains EIe=tric Cooperatht. Inc. Docket No. 11904 pr-opotsed Rate Scheduks and Pro Forma Revenues Scheduk S418-2 Page S of 6 BILL NO PROPOSED CUSTOMERCLASS DETERMINANT'S RATE REVENUES COTPON GINS customer Mane 231 SSODO $1I,550 Demand Charge (Apr —Sept) 2.170 S8A0 SV7 W Energy Charge Apr —Sept AlI kWb 233. 90 $0.03313 r S7,739 Oct —MU I s t 100 k" I k W 4,341.266 SO.07604 $330.110 Remaining M 8,124.724 SO.03S41 5287,E+96 Total 12+699M S654.4SS QTL.FIELD —SECONDARY Total BMs Horsepower Charge Energy Charge OILPIIZD — PRIMARY Customer Charge Demand Charge Energy Charge 10,758 231591 S6A0 S1.389A46 37 J0'74.314 SOM348 $1.241,248 37.074,314 $2,630,794 256 SSODD 3129W 1Sy38 $7.73 $123,520 6,677,091 SOMM $183,754 6i677A91 $320M3 Public Unity Commission oiTca u South Plaim Electric C.00perathe, I= Docket No. 11904 8 Q.LING LIGHTING Public Street Lights Customer Charge Energy Charge Outdoor Lighting 100 Watt High Pressure Sodium 175 Watt Mercury Vapor 150 Watt High Pressure Sodium 400 Watt Mercury Vapor 175 Watt Halide 400 Watt Halide 1000 Watt Halide Multiple Unit Discount; 2t—SO Lights Multiple Uait Discount: Over SO Lights Equipment Rental - 6,000 Lumens . Equipment Rental —12AW Lumens Total TOTAL PRO FORMA BASE RATE REVENUES OTHER REVENUE TOTAL PRO FORMA REVENUES PROPOSED REVENUE REQUIREMENT Schcduk SMB-2 page 6 of 6 REVISED PROPOSED 36 S 179S sw 371,189 $0.02696 S 10A07 18,862 $SAS $110,343 56,587 SS.85 S331 A34 1,909 58.48 S 16,188 5,727 $8.48 $48,S65 SS.BS $8M $17,50 ($02S) ($0-c $29 53.E S2,S28 S4.Si $S19,312 521.3W S29 $127;M4 $21,434.33 521.434,453 220 Public Utility Commission of Texas Memorandum TO: Michael Etchison, General Counsel FROM: Stephen M. BenensonAlectric DATE: May 14, 1993 SUBJ: Response to Examiner's Order No. 3, Docket No. 11904, Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates This memorandum responds to a request in Examinerfs Order No. 3 for revisions to Schedules SMB-1 through SMB-3, in light of a corrected Staff memorandum filed by General Counsel on May 10, 1993. There are no revisions to the above mentioned schedules due to this corrected memorandum. The corrected memorandum from Staff analyst Roland Kinney reflects changes to the rate of return for the Cooperative due to normalized irrigation usage. Schedules SMB-1 through SMB-3 already reflect this normalization. As stated in the corrected memorandum, Mr. Kinney recommends approval of the requested rate increase of $924,053. Since Schedules SMB-1 through SMB-3 are based on this same total revenue increase, this corrected memorandum does not change these schedules as filed. However, the Cooperative has advised me of an error in the proposed Lighting rates in Schedule SMB-2. Page 6 of this schedule lists a proposed credit for "Over 50 Lights" of 25 cents. This should be a credit of 50 cents. Since no customer received this credit during the test year, total revenues are not affected. _I have attached a revised page 6 of Schedule SMB-2 to this memorandums. ' Pvbtk Utaity Commission of Tcras Schcduk SMS-3 Soutb PlAm Eleart C40peratk, 104 pocket No.11904 Rcs0entlal Gil Compar6ocu kWh E &dn; Proposed Iccreue Increau Residential Qus Usa PC Sill Bw S % Residentlal — Regular Rite Soo Ipm $3336 $60.71 S3SD9 $64.17 S1.73 S3A6 5.18% 5.70% 1,500 S88D7 $9326 $5.19 Sm% Spaoc Hcat — Separate Meter Nov — Apr 50o S13A2 Sisis $1.75 130j'% 1.000 S2624 $3035 $3.51 132M 1.500 W26 S4S.S3 $5.26 13M% May — Oct 500 $2736 S29D9 S1.73 6.32% lAw $54.71 SS8.17 $3.46 632% IX S82D7 $8726 SS.19 632% Space Heat — Single Meter Nov — Apr SW $3336 S3SD9 $1.73 S.19% I= W.78 $5026 Sla 7.45% I'Sm $6020' S6SA4 $524 lum May — Oct 500 $3336 S35D9 $1.73 5.18% 1 m S6071 S6<17 $3.46 S.70% Ix SM-07 $9326 $5.19 Sm% Water Heater Soo $3336 S35D9 $1.73 5.18% Im $5098 WAS S3.47 621% Ix S7933 S8354 SS.20 C61% Space Heat — Water HOW /Space Heater Nov —Apr Soo $3336 S3SD9 $1.73 5.18% 1 M S5098 SUAS $3.47 6m% I's00 SCAAD $69.63 SS22 8.11% May — Oct Soo S3336 $35D9 $1.73 5.19% I,= $5098 SUAS $3.47 620% I $7834 $83.54 SS20 6A3% I t LA ' :: c: m m LAW OrrtcEs McG;xxis, LOCH IDGE & KILGORE, LLP. 1300 CAPITOL CENTCR ' 2830 TEXAS COMMERCE TOWER 919 CONGRESS AVENUE - r a 300 C++ARLCS COURT Goo TRAVIS STREET ,vim~ J�'r 1 ^' jpj+KpRTN ,RCSA STREET LUSTIN. ?E7C,5 78703 • HOUSTON. TEXAS 77002 &AN "ANTONIO. TEXAS 74tos (713) ZZ7•6000 (512) 405-E000 - (210) Zta-M31 PAX (713) ua•CSOS PAX (Sit) 405-6003 lJ�:„ wonn's saw 9" Nursac (512) 495-6046 June ll, 1993 Mr. Clay Harris Hearings Examiner Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Mr. Harris: This letter is in response to your request for corrections to the proposed order in the above -captioned proceeding. The Cooperative's proposed corrections are as follows: Finding of Fact 19. For the period ending September 30, 1992, irrigation usage was 36,001,843 kWh rather than 38,874,730 kWh as stated in this finding. It appears that the kWh stated in finding 19 relates to the calendar year 1992. Ordering Paragraph 2 (page 11 of the proposed order). This provision sets up a tariff review process after the Commission's final order. This process is not necessary because the staff has already reviewed and approved the Cooperative's revised tariffs. A copy of the staff s approval accompanies this letter. Ordering paragraph 2 should be revised to state: The tariff sheets recommended for approval by the general counsel are approved effective on the date of this order. To facilitate this request, I am depositing clerk, 6 copies of tariffs that are identical to the tariffs which were reviewed and approval by the General Counsel. No changes with the tariff in all respects recommended for have been made. Z2 Mr. Clay Harris June 11, 1993 Page 2 As I am sure you are aware, the purpose of substantive rule 23.23(c) is to establish a process for expediting electric cooperative rate cases. A tariff review process after the date of the Commission's final order is neither necessary nor consistent with the purpose of this rule. Your assistance in making the corrections indicated above is most deeply appreciated. Yours very truly, 6� Cam ell McGinnis ECM/lm Enclosures cc: General Counsel, PUC Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative 0 8a\8\BPL%=3\R=\BA=$3.LTR DOCKtt NO. 11904 APPLICATION OF SOUTH PLAINS ' I'U'BL� i(r G°TILITY CONIMISSION ELECTRIC COOPERATIVE, INC. - FOR EXPEDITED AUTHORITY`OF TEXAS TO CHANGE RATES PURSUANT TO P.U.C. SUBST. R.2323(c) GENERAL COUNSEL'S APPROVAL OF PROPOSED TARIFFSHEETS The General Counsel of the Public Utility Commission of Texa,h representing the public interest, recommends approval of the proposed tariff sheets submitted on May 12, 1993, by South Plains Electric Cooperative, Inc. The memorandum of Staff witness Stephen M. Benenson memorializing his approval is attached hereto. Respectfully Submitted., Nolan F. Ward/' ,r ' General u el Bret �. Slocum Deputy G neral fqunsei .w �a fn .ewe Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd., Suite 109W Austin, Texas 78757 (512) 458-0278 MEE/& N:\UEM\119"4XD0C Pub& Ualiy Commission of Texas Memorandum TO: Michael Etchison, General Counsel P FROM: Stephen M. Benensons lectric DATE: May 24, 1993 SUBJ: Docket No. 11904, Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates I have reviewed South Plains Electric Cooperativets proposed tariffs filed at the Commission on May 12, 1993. The tariffs are in compliance with Staffs recommendations, and I recommend that they be approved. car Orrtccs McGiwwis, LOC$HYDCrE & KILOOBE. LLP 1300 �OIrQL cepir[N &*SO rCXAS COMMC11GC TOWCO •oo rR.ws STOCCr NOU3rON. roux 77002 (713) szr • 4000 •A: (713) 936.OSGS 010 CONGOCSS AVCNUC ♦CSTW. TEXAS 78701 (514 .os •e000 r*_ (aW 400.4093 ..r+v•soft .... .,..a (512) 495-6046 May ;2, 1993 Mr. Michael Etchison Assistant General Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd. Austin, Texas 78757 a 300 C"Aw,,CS COUNT Iros NOwr« "CZA sr•CCr ILAN ANTONIO• rC" 70=06 (910) 824•1&31 VAX (810) 226. b1s RE: Application of South Plains Electric Cooperative, Inc. for Expedited Authority to Change Rates Pursuant to PUC Subst. Rule 23.23(c); PUC Docket No. 11904 Dear Mr. Etchison: Enclosed is a draft of rate schedules Which have been revised to conform with with the staff recommendations in the above - captioned proceeding. Please request that the staff review the enclosed rate schedules to be sure that there are no errors and advise me of the results of their review. If the tariffs are acceptable, I would like to have them filed as agreed tariffs in the above -captioned proceeding with the request for implementation upon Commission final order. Thank you for your assistance in this matter. Yours very truly, Campbell McGinnis ECM/lm Enclosures cc: Bolinger, Segars, Gilbert & Moss South Plains Electric Cooperative �:�s�apt�►.�a�aazr�saoa.trs Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 2 Tariff for Electric Service RievisLon Page 1 SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .01 GrLLING ADJUSTMENTS TAMP PUBLIC UTILITY COMMIEDON Of TEAS JLlN 17 '93 GcL,tET 11904 COINTRV_'x The Cooperative shall adjust all !tills in accordance with the foll(nring adjustments if applicable. The Power Cost Recovery Factor (PCRF) shall be applied to each am sold in addition to any monthly minimum, contract minimum, or annual aLnLzzum charges and shall not apply toward satisfying any of said minimum charges. Power Cost Recovery Factor (PCRF) The monthly charges shall be increased or decreased on a uniform per MM basis computed monthly as follows: PCRF a (A-B+C)/DMs (A-B-C)/RWSs Where: PCRF • Power Cost Recovery factor (expressed in $/MM) to be applied to estimated energy sales for the billing period. A • Total estimated purchased electricity cost from all suppliers including fuel for the billing period. H Total estimated purchased electricity cost from all suppliers including fuel which are included in the Cooperative base rates. The base power cost is computed as: 8 ` (D) (ems) D e Base power cost in $/RWS sold of $0.042135 for all billing months. C • Adjustment to be applied to the current monthly billing to account for differences in actual purchased electricity costs and actual PCRF revenues recovered in previous periods. Section Sheet No. SOOTS PLAINS ELECTRIC CDOPSRATIVE, INC. 20 3 k Tariff for Electric Service Revision Page 1 SECTION TITLE: puc PUSUC UTILITY COMI&CSSIGV OF TEXAS STA" APPROVED RATE SCHEDULES 11904 JU�� 17 '03 Cc„�R CONTROL It APPLICABLE TO ALL AREAS TARIFF CLERK IMs s Total estimated energy sales for billing period. NOTE: SASE POWER COST • COST OF PURCHASED POWER TOTAL MIR SALES 13,386,267 • 0.042135 317,702,856 11 v Section Sheet No. SOOTS PLAINS ==RIC COOPERATIVE, INC. 20 4 Tariff for Electric Service Revision. page 1 SECTION TITLE: ppC F�'uliC �i�LiTf % 8 ri�iS-J V OF TEXAS STAMP AP -PROVED RATE SCHEDULES JUN 17 '921 cx,fs 11904 APPLICABLE TO ALL AREAS T:"-.3Fir Ci_MftY. .02 RESIDENTIAL SERVICE Availability Available to Customers for all farm, shop and home uses, (single family residence or ,- unit apartment), including lighting, heating, power and home Water supply, subject to established rules and regulations, but not applicable for irrigation or seasonal agricultural'processing use. Type of Service . . Single phase and three phase at available secondary voltages. Frequency and voltage shall be subject to reasonable variation. Recjular Residential Rate Customer charges $6.00 per month Energy charge: $.05817 per kWh Minimum Charge The minimum monthly charge under the above rate shall be $6.00 where 10 KVA or less of transformer capacity is required, but not inciudiaq any applicable billing adjpstments provided for under Tariff Section 20.01. For members requiring more than 10 KVA transformer capacity, the minimum monthly charge shall be increased at the rate of $1.00 for each additional EVA or fraction thereof required. Payment of the minimum charge shall entitle the member in all cases to the use of the number of kilowatt hours corresponding to the minimum charge in accordance with the rate. Electric Living Service n Space Heater - Separate Meter It the Customer shall elect to have all energy used by such space seating metered separately from other uses, then such separate use will be billed as follows: Customer Charges $0.00 per month Energy Charge: November -April $0.03035 per kWh • Kay -October $0.05817 per kWh R Section Sheet No. SOUTH PLAINS ELECTRIC C10OPERAr1VE, INC. 20 S Tarsi! for Electric Service Revision Page 1 iiibL"i Usi'lli 4;_i: tttiti:,viViri U IrXX SECTION TITLE: PUC APPROVED STAR RATE SCMULES t Q 1.7 4J iV.1 '_ C: 1 P APPLICABLE TO ALL AREAS :_.,. I- Space Heater - Uncle Meter► Customer Charges $6.00 per month Energy Charge: November -April First $00 kWh $0.05817 per kWh Samaining kWh $0.03035 per kWh Say -October All kWh $O.05817 per kWh Water Heater When Customer has in regular use a permanently installed 240 volt, 20 gallons or greater, storage type water heater of not greater than 5.5 kilowatts, individual rated capacity, billing will be as follows: Customer Charge: $6.00 per month Energy Charge: First S00 kWh $0.05817 per kWh Next 600 kWh $0.03873 per kWh Additional kWh $O.OSS17 per kWh All Electric Space Heat When Customer has in regular use permanently installed space heating equipment of an aggregate rated capacity of 5 kilowatts or more, excluding bathroom heater,. billing will be as follows: Customer Charge: $6.00 per month Energy Charge: I First 500 kWh $0.05817 per kWh Next $00 kWh $0.03873 per kWh Additional kWh $0.05817 per kWh Space Heat - water Heater/Space Heater When customer has water heating in combination with all -electric spare heating, billing will be as followst Customer Charge: $6.00 per month SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service Section Sheet No. 20 1 6 Revision Page 1 SECTION TZ=: PUc PUBLIC U118LIAV. D.-O ilSSION OfF Tr'XAS STAR r4Fi' RATE SCHEDU=S �M17 1904 APPLICABLE TO ALL AREAS Cry-.; # ^f/1'! � 1 f1i�./FF t� Energy charge: November -April first 500 kWh _ Next S00 kWh Remaining kWh May -October first S00 ks;h Next 500 1Wh Remaining kWh Billing_ Adjustments Reference Tariff Section 20.01. i, R $0.05817 $0.03873 $0.0303S $0.05817 $0.03873 :o.ose17 -Tj R Terms of Payment Each bill for utility service(*), regardless of the nature of the service(s), is due upon r*ceipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If fall payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Section Sheet No. SOUTH PLAINS 6I.ECTRIC COOPERATIYB, INC. 'tariff 20 7 for Electric Service Revision Page 1 SECTION TITLE: PUC STAMP PU6lIC UTILITY COMMISSION of TEXAS RATE SCHEDULES , APPROVED APPLICABLE TO ALL AREAS .03 LARGE POWER SERVICE Availability r' JUN 17 '93 DOCKET 11904 CONTROL # TARIFF CLERK Available for general and industrial service to Customers, including large schools and churches, having capacity in excess of 50 VA for all uses including lighting, heating and power and municipal water pumping, subject to the established rules and regulations; not available for cotton gins, oil well, or irrigation pumping. Type of Service Single-phase and three-phase at available primary or secondary voltages; motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate 4 Customer Charges $50.00 per month; Demand Charges S 8.00 per kw of billing demand per month; plan, 8aergy Charges S 0.04650 per kWh for first 175 EST S 0.02622 for all remaining M. Power Factor Adjustment The Customer agrees to maintain unity power factor an nearly as practicable. To correct for average power factor lower than ninety-five percent (M), for Customers if and when the Cooperative deems necessary, an adjustment will be made by increasing measured demand one percent (lt) by which the average power factor is less than ninety-five percent (95%) lagging. Minimum Monthly Charge The minisaum monthly charge shall be the bighest one of the following charges as determined for the Customer in question, but not iaeludinq any applicable billing SOUM PLAINS ELECTRIC COOPERATIYB, INC. Tarif f for Electric Service Section 20 Revision 1 Sheet No. e Page SECTION TITLES PUC APPROVED STAMP RATE SCHEDUXXS JUW 17 '93 CGUCKET 11904 APPLICABLE TO ALL AREAS adjustments provided for under Tariff Section 20.01. CCNTROLft TARIFF CLERK 1. The minimum monthly charge specified in the contract for service. 2. A charge of $1.00 per RYA of installed transformer capacity. Determination of Billing Demand The billing demand shall be the -maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered, as indicated or recorded by a demand meter and adjusted for power factor as stated above. Conditions of Service 1. Delivery Point -Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. All wiring, pole lines, and other electric aquipment (except the Cooperative's metering equipment) on the load side of the metering point shall be owned and maintained by the Customer. 2. Exclusive Use - Service delivered hereunder is for the exclusive use of the Customer and may not be resold.or delivered for the use of others. 3. Metering - When primary metering equipment is used, it shall be located at the delivery point. Sowever, the Cooperative shall have the option of metering at secondary voltage and adding two percent to the metered kilowatt hours to compensate for transformer losses. In the event secondary metering is used, it will be located on the load side of the Customer's transformer structure. Billing- Adjustments Reference Tariff Section 20.01. SECTION TITLES RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Section Sheet No. SOUTH PLAINS ELECTRIC COOPERATM, INC. 20 9 Tariff for Electric Service Revision Page 1 PUC PUBLIC UTILITY COMMISSION OF TEXAS TAK APPROVED Jtf 17 '93 Docar 11904 TARIFF CLERK Each bill for utility ssrvice(s)', %gardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is duo on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. Section SOOTS PLAINS ELECTRIC COOPERATM, INC. 20 Tariff for Electric Service Revision 1 SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .04 IRRIGATION SERVICE RATES Availability Sheet No. 10 Page POC PUBLIC UTILITY COMMISSION OF TEXAS STAMP APPROV =D JUN 17 '93 Docur 11904 CONT130L x T&W7 CLERK Available to Customers of the Cooperative for service to irrigation pumps and subject to the established rules and regulations of the Cooperative covering this service. Type of Service Single or three-phase, 60 cycles, at standard secondary voltages. The Cooperative may limit the maximum rating of motors where such may cause interference to other Customers. Frequency and voltage shall be subject to reasonable variation. Rate Summer (July through September billing) Energy Charge: First 200 kWh per horsepower - $0.12415 per kWh, am.-lusive of billing I� adjustments under Tariff Section 20.01, per season. $0.06618 per kWh for all kWh in excess of 200 kWh per horsepower per season, exclusive of billing adjustments under Tariff Section 20.01. winter ( October through June billing) L Energy Charge: $0.05924 cents per kWh per season, exclusive of billing adjustments under Tariff Section 20.01. Demand Side Management T Eligible customers may receive demand side management credits in accordance with the Cooperative's Demand Side Management Rate. E Section I Sheet No. SOQTH PLAINS ELECTRIC 000P8RATIYE, INC. 20 11 Tatif f for Electric Service Revision Page 1 SECTION TITLEs POC STAHP PUBLIC UTILITY COMMISSION OF TEXAS RATE SCHMULES APPROVED JUN 17 '93 Doi m 11904 APPLICABLE TO ALL AREAS CONTROL## Determination of Horsepower The horsepower billing purposes shall be the motor manufacturer's nameplate rating of horsepower output, except that, if the Cooperative so elects, it shall be determined by actual measurements of power input during a period of maximum normal use, less an allowance of ten percent (10%) of input for motor losses. All motors under S.0 horsepower will be billed at the 5.0 horsepower rate. Annual Minimum Charge The annual minimum charge under the above rate shall be SIS.00 per horsepower of connected load but not less than $75.00 and shall be billed at $2.50 per horsepower per mouth for the billing months of April through September. In the event electric facilities are initially made available for service for only a portion of the year, such annual -Iofmum will be as follows: P a. Service connected in Septembers b. Service connected in Octobers c. Service connected in Novembers d. Service connected in Decembers =b/horsepowert but not less than $30.00 $4/horsepower, but not less than.$20.00 $2/horsepower, but not less than $10.00 No annual minimum Should the total of all monthly billings in a 12 month period be less than the annual minimum charge, the consumer will pay the difference between the total billing exclusive of billing adjustments under Tariff Section. 20.01, and the annual minimum charge specified therein. SOUM PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLES RATE SCHEDULES APPLICABLE TO ALL AREAS Stan_ Irrigation Service PVC STAMP Section Shoat No. 20 1 12 Revision I Page 1 PUBLIC CF 76XA AFPROVED JUN 17 '93 cumu 11904 CONTROL u TARIFF CLERK To defer or prevent the Cooperative from retirement of an We irrigation service for a period of one year or less, the Customer may place an irrigation service on standby. The Cooperative will disconnect the service and any remove the meter and transformers for use elsewhere. Idle Service Annual Charges $10.00 per horsepower per year, but not less than $50.00 nor more than $300.00, billed not later than April 15 each year, plus; Reconnect Fees $25.00 with a minimum of seventy-two (72) hours notice, the Cooperative will reconnect the facility, so that the Customer may receive electric service under one, of the above rates. Should the Customer have the standby service changed to an active service later in the irrigation year, any amounts paid as idle Service Charges (except Reconnect Fee) shall be allowed toward the applicable Annual Minimum Charge above. Power Factor Adjustment The Customer agrees to maintain unity factor as nearly as practicable. The horsepower for billing purposes will be adjusted for Customers with 50 horsepower or score to correct the average power factors lower than ninety-five percent (M), and may be so adjusted for other Customers if and when the Cooperative deems necessary. Such adjustments will be made by increasing the horsepower one percent (lt) by which the average power factor Ls less than ninety-five percent (95 •) lagging. Sillfnq Adjustments Reference Tariff Section 20.01. Terms of Payment Each'bill for utility service(s), regardless of the nature of the ssrvice(s), is due upon Section Sheet No. SORTS PLAINS ELECTRIC OOOPERATI", INC. ZO 13 Tariff for Electric Service Revision Page 1 SECTION TITLEs STAHP PUBLIC UTILITY COMMISSION OF TEMS RATE SCHE VLES APPROVED JUN 17 '93 IoCKIT 11904 APPLICABLE TO ALL AREAS CONTROL # TARIFF CLERK receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Ooo'perative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03 SOCTE PLAINS ZLECTRIC COOPERATIVE, INC. Tar if f for Electric Service Section I Sheet No. 20 14 Revision I Page 1 t'U6LiC UTILITY t;"INIISSION OF TEXAS SECTION TITLES STA" APPROVED RATE SCHED=S JUN 17 '93 DOCKET 11904 APPLICABLE TO ALL AREAS .05 GENERAL SERVICE Availability CONTROL # TARIFF CLERK Available for commercial, industrial, municipal water systems, apartment houses, and three-phase service having a capacity of 50 KM or less, for all uses including lighting, heating and power, subject to the established rules and regulations. Rate is not available for cotton gins, oil wells or irrigation pumping. Type of Service Single-phase and three-phase at available secondary voltages motors having a rated capacity in excess of ten horsepower must be three-phase. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charges $17.95 par month Energy Charges S 0.05908 for all kWh par month minimum Monthly Charge The minimum monthly charge under the above rate shall be $17.9S wherar 10 AVA or less of transformer capacity is required, but not including any applicable billing adjustments provided for under Tariff Section 20.01. For Customers requiring more than 10 XV& of transformer capacity, the minimum monthly charge shall be increased by $1.00 for each additional KVA or fraction thereof required. Minimum Annual Charge for Seasonal Service Customer requiring service only during certain seasons not exceeding nine months per year may guarantee a minimum annual payment of twelve times the W altu a monthly charge determined in accordance with the foregoing section, in which case there will be no minism— monthly charge. 9 SOUTH PLAINS BLBCTRIC COOPSRATIYB, INC. Tariff for Electric Service SECTION TITLEt RATE SCHEDULES APPLICABLE TO ALL AREAS Space Heating Section Sheet No. 20 is Revision Page 1 PUC PUBLIC UTILITY CO,MMISSIvAl of TExk;; STAMP AFPROVED JUN 17 '93 Doe;ca 11904 CONTROL # TAR'Fir CLURK when a Customer regularly uses permanently installed electric heating equipment, 5 XW or more of total capacity in one building and energy for the space heating equipment is measured by a separate meter, all kWh so metered during the November, December, January, February, March and April billing periods will be billed at $0.02660 per kWh subject to the following conditions: 1. The Customer's wiring will provide for a main service meter to measure kWh used for all purposes except space heating and air conditioning compressors, and further provide for a separate meter to measure only energy used exclusively for space heating equipment and air conditioning compressors. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service (s), regardless of the nature of the service (a), is due upon receipt and delinquent 16 days after Lasuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment Ls not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Penalt Reference Tariff Section 30.03. 9 Section Sheet No. SOOTS PLAINS ELECTRIC COOPERATM, INC. 20 16 Tarif f for Electric Service Revision Page - 1 SECTION TITLEt RATE SOMD=S APPLICABLE TO ALL AREAS .06 COTTON GIN SERVICE Availability PVC STAHP PUBLIC UTILITY COMMISS1011 OF IEUS APPROVED Jf 17 '93 iyocKEr 11904 CONTao1P TJC�RIFF CLERK Available for power service to cotton gins and supplemental uses, and for other seasonal uses, excluding energy for standby or shared service with another source of electric power (except qualifying facility). Z)►pe of Service Three—phase, 60 hertz, A.C. at Cooperative's available voltages. Service supplied hereunder will be at a single point of delivery and measured through one meter. Frequency and voltage shall be subject to reasonable variation. Rate T 1 Monthly Service Availability Charges $50.00 Summer Season (April through September Billing): Demand Charge: $8.00 per EW per month plus Energy Charges $0.03313 per kWh per month Winter Season (October through March Billing): Q Energy Charges First 100 kWh per KW of demand per month $0.07604 per kWh All additional kWh per month $0.03541 per kWh SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Annual Hinimum Charge FCC STAMP Section Sheet No. 20 1 17 Revision Page 1 PUBLIC UTILITY CO ,'WISS10A OF i.Y/ice APPR" VED JUM 17 '93 aye,; 11904 CONTROL TARIFF CLERK The annual minimum charge under the above rate shall not be less than SG.S0 per connected KVA, but not including any applicable billing adjustments provided under Tariff Section 20.01. Should the total of all monthly billings be less than the annual minimum charge, the Customer will be billed for such difference with the March billing of the year. Off -Season Disconnection Customer is encouraged to disconnect the service during the Summer months that the service is not required. However, one temporary reconnect will be made for a period not to exceed 24 hours for motor test, provided the Cooperative is not experiencing a loading peak on the substation furnishing service to the load. Any kWh used will be billed. XW demand will not be billed; the demand register will be reset. Additional temporary reconnects will be made and billed at $2S.00. Determination of KW Demand The demand shall be the mazimum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month in which service is rendered hereunder as indicated or recorded by a demand meter adjusted for power factor. Power Factor Adjustments - The Customer agrees to- maintain unity power factor as nearly as practicable. The KW demand will be adjusted for Customers to correct for average power factors lower than ninety-five percent (95t), if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (it), for each one percent (1%) by which the average power factor is less than ninety-five percent (95t) lagging. Billing Adjustments Refetence Tariff Section 20.01. SECTION TITLES RATE SCHEDULES APPLICABLE TO ALL AREAS Terms of Pavment Section Sheet Ro. SOUTH PLAINS ELECTRIC COOPERATIVE* INC. 20 18 Tariff for Electric Service Revision Page 1 ' PUC PUELIC UTILITY COMMIS')40 OF TE,';AS TAM APPROVED JUN 17 M DncK r 11904 CONTROL # TARIFF CLERK Each bill for utility service (s) , regardless of the nature of the service (s) , is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, is which case payment is due on the next work day. If full payment is not received is the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in accordance with the rules of the appropriate regulatory authority. Section I Sheet No. SOUTS PLAINS ELECTRIC COOPSRATIV8. INC. 20 19 Tarif f for Electric Service Revision Page 1 SECTION TITLEs PUC PUBLIC UTIUTY COMMISSION Of TEXAS STAMP AFPROVM RATE SCHEDULES IJUN17'93mc,lu .119 0 4 APPLICABLE TO ALL AREAS CONIMOL ## TARIFF CL.'RK .07 OIL FIELD SERVICE • SECONDARY VOLTAGE Availability Available to Customers of the Cooperative for service to oil well pumps (well head service) and for other uses directly related to oil production where energy is used exclusively by electric motors and subject to the Cooperative's rules and regulations covering this service. Tyne of Service Single-phase or three-phase, 60 hertz, at standard secondary voltage. The Cooperative may limit the maximum horsepower rating of motors served with single-phase service where such may cause interference to other Customers. Frequency and voltage shall be subject' to reasonable variation. Rate Horsepower Charge: $6.00 per horsepower per month, plus, , 8aergy Charges $0.03348 per kWh per month. Determination of Horsepower The horsepower for billing purposes shall be the manufacturer's motor nameplate rating, or at its option, the Cooperative may determine the horsepower by test under conditions of maximum operating load. Power Factor The Customer agrees to maintain unity power factor as nearly as practical. The horsepower for billing purposes will be adjusted to correct for average power factors lower than ninety-five percent (M) if and when the Cooperative deems necessary. Such adjustments will be made by increasing the horsepower one percent: (lt) by which the average horsepower is less than ninety-five (95`) lagging. SOUTH PLAINS ELECTRIC COOPERATM, INC. Tariff for Electric Service SECTION TITLE: PVC STAMP RATE SCHEDULES APPLICABLE TO ALL AREAS Mlninn= Monthly Charge Section I Sheet No. 20 20 Revision Page 1 PUBLIC UTILITY OF JEXPz APPROVED JUN 17 '93 Docar 11904 CONTROL # TARIFF CLERK The minimum monthly charge under the above rate shall be the horsepower charge and in no event shall it be less than =17.95 but not including any applicable billinq adjustments provided for under Tariff Section 20.01. Billing Adjustments Reference Tariff Section 20.01. Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day fails on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection its accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30,03. SOOTS PLAINS MZCTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .08 PRIMARY VOLTAGE SERVICE Availability Section Sheet No. 20 1 21 Revision Page 1 PVC C PUBLIC UTILITY COMMISSION OF TEXAS APPROVED JW 17 '93 DccKu 11904 CONTROL TARIFF CLERK Available for gil field pumping or Customer -owned primary distribution systems. Type of Service 4 Three-phase, 60 hertz, at the Cooperative's standard primary distribution voltages. Frequency and voltage shall be subject to reasonable variation. Rate Customer Charge: $SO.00 per monthl l Demand Charges $7.75 per month KW of billing demands plus Energy Charges $0.02752 per kWh per month Determination of Billing Demand The billing demand shall be the maximum kilowatt demand established by the Customer for any period of fifteen consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as followss Power Factor Adjustment The Customer agrees to maintain unity power factor as nearly as practicable. Demand s charges will be adjusted for Customers to correct for average power factors lower than ninety-five percent (M) if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (It) for each one percent (1t) by which the average power factor is less than ninety-five percent (95%) lagging. Billing Adjustments - Reference Tariff Section 20.01. SOMM PLAINS ELECTRIC COOPEP.ATrn, INC. Tarif f for Electric Service Section Sheet No. 20 1 22 Revision j Page 1 j SECTION TITLE: PUC PUBUC UTILITY COIN ISSiO;d OF TEXAS STAMP APPROVED RATE SCHEDULES JUN 17 '93 cc;;tr 11904 APPLICABLE TO ALL AREAS Minimum Monthly Charge CONTROL TAiRlrP CLERK The minimum monthly charge sh'alr be the highest one of the following charges as determined for the Customer in question, but not including any applicable billing adjustments provided for under Tariff Section 20.01. 1. The minimum monthly charge specified in the contract for service. 2. A charge of $1.00 per M of installed transformer capacity. Conditions of Service 1. Delivery Point- Unless otherwise specified by the Cooperative, service will be delivered to the boundary of the Customer's lease or premise. The delivery point shall be the point of attachment of the Cooperative's primary lines to the Customer's electric lines or system. All airing, pole line, and other electric equipment (except the Cooperative's meteriaq equipment) on the load side of the metering point shall be owned and maintained by the.Customer. 2. Exclusive Use - Service delivered hereunder is for the exclusive use of the Customer and may not be resold of delivered for the use of others. a. Metering - when primary metering equipment is used, it shall be located at the delivery point. However, the Cooperative shall have the option of metering at secondary voltage and adding two percent (2%) to the metered kilowatt hours to compensate for transformer losses. In the event secondary metering is used, it will be located on the load side of the Customer's transformer structure. Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection in Section Sheet No. SOUTE PLAINS SLBC'TRSC COOPERATIVE, INC. 20 23 Tariff for Electric Service Revision Page 1 SECTION TITLE t PQC Pl!$L" UTI 1 Ty C0,11-1- ��^-SIGN OF i EX �` STA" APPROVED RATE SCNEDMES JUN 17 '93 tOCxET 11904 APPLICABLE TO ALL AREAS CONT�L # TARIFF CLERK accordance with the rules of the appropriate regulatory authority. Penalty _ Reference Tariff Section 30.03. Section Sheet No. / SOUTH PLAINS ELECTRIC COOPERATIVE, INC. 20 24 Tariff for Electric Service Revision Page 1 SECTION TITLE: PUC PUBLIC UTILITY CC"MISSION O I £XAS I STAMP APPROVED RATE SCHEDULES APPLICABLE TO ALL AREAS .09 OUTDOOR LIGHTING SERVICE Availability JUN 17 '93 ©LcKET 11904 CONTROL # TARIFF CLERK Available to Customers of the Cooperative, except where prohibited by law or ordinance for dusk to dawn outdoor lighting in close proximity to existing overhead secondary circuits. Also, available to incorporated cities, towns, and villages for delivery and use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to the established rules and regulations of the Cooperative. Type of Service Vametered electric energy to lighting units, furnished, installed and maintained by the Cooperative. Frequency and voltage shall be subject to reasonable variation. Rate Per Light for Month Light mounted and connected to overhead secondary unit. ITS Watt Mercury Vapor $ S.SS/month 400 Watt Mercury Vapor = 8.48/month 100 Watt HP Sodium = S.SS/month ISO Watt HP Sodium = 8.48/month 17S Watt Balide : S.85/month 400 Watt 8alide i 8.52/month 1000 Watt 8alide $17.50/month Multiple USE Discount 21 through 50 units: over SO units: Billing Adjustments $0.2S per unit per month SO.SO per unit per month Reference Tariff Section 20.01. A N N N N 1 `a SOUTS PLAINS z=cTRSc OOOPERATM, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Conditions of Service PUC STAMP rSection Sheet No. 20 1 2S Revision I Page I PUBLIC UTiUTY COIANI1SS101`4 OF TEXAS APPFOVEO AN17'93Docm 11904 CON:TPYCLV- T RIFF CLERK 1. The Cooperative shall furnish, install, operate, and maintain the outdoor lighting equipment including lamp, luminaire, bracket attachment and control device on an existing wooden pole of the Cooperative, when one is readily available, electrically connected so that the power for operation of light does not pass through the meter for the customer's other usage, at a location mutually agreeable to both the Cooperative and the Customer. 2. The Cooperative shall -maintain the lighting equipment, including lamp replacement, at no additional cost to the Customer within 72 hours after the Customer notifies the Cooperative of the need for maintenance of the lighting equipment. 3. The lighting equipment shall remain the property of the Cooperative. The Customer shall protect the lighting equipment from deliberate damage. 4. The Customer shall allow authorized representatives of the Cooperative to enter upon the Customer's premises and to trim trees and shrubs as necessary for maintenance of the lighting equipment and for removal of the lighting equipment upon termination of service under this schedule. 5. The Cooperative and Customer may execute an agreement for service under this schedule for a period of not less than one (1) year. 6. Should a city, town, or village designate use of metal standards, then the added average cost in place of such units above the average installed cost of a thirty—foot (301) wooden pole will be paid by the customer. 0 Equipment Rental Only Should the Customer have metered electric service available, and it is not convenient for the Cooperative to furnish unmetered service for the outdoor lighting installation, the Cooperative will furnish an outdoor lighting unit to the Customer, except lose electricity at these rates: ? 17S watt Mercury vapor S3.OS/month L 400 watt Mercury vapor S4.8S/month 100 Watt HP Sodium S3.05/month N ISO Watt HP Sodium S4.8S/month 14-1 SOUTE PLAINS ELECTRIC COOPERATIVE, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .10 PUBLIC STREET LIGHTING SERVICE Availability Section Sheet No. 20 27 Revision Page 1 PUCI PUBLIC UTILITY CONIMISSION Of TEXAS wr u APPROVED ED JUN 17 '93 DocKa 11904 CONTROL # iAR1F+ CLERK Available to incorporated cities, towns and villages; and the state of Texas, for use within areas certified to the Cooperative by the Public Utility Commission of Texas, subject to established rules and regulations. Type of Service Single-phase service at primary or secondary voltage for delivery to street lighting facilities and systems owned and maintained by the agency. frequency and voltage shall be subject to reasonable variation. Service may be unmetered and kWh will be calculated. Rate Customer Charge: SIMS per month; plus, Energy Charges $0.02696 per kWh for all kWh used per month. Min4mum_Monthly Charge The minimum monthly charge under the above rate shall be the customer charge plus $1.00 per lighting unit served from the Cooperative's distribution system, but not including any applicable billing adjustments provided under Tariff Section 20.01. Conditions of Service 1. Service will be delivered at the Cooperative's distribution system, with all necessary wiring therefrom to the street lighting system to be furnished and maintained by the Customer. 2. Service delivered hereunder will be used for street and roadway lighting purposes. SOOTS PLAINS ELECTRIC 00OPERATM, XMC. Tariff for Electric Service Section Sheet No. 20 1 28 Revision ! Page 1 1 SECTION TITLES POC PUBLIC UTILITY COMMIsS1011 Of TEXAS STAMP APPROVED RATE SCHEDOLES JUN 17 '93 Doug 11904 APPLICABLE TO ALL AREAS COhITR-CL 3FTARIFF CLERK Billing Adjustments Reference Tariff Section 20.01.' Terms of Payment Each bill for utility service(s), regardless of the nature of the service(s), is due upon receipt and delinquent 16 days after issuance unless such day falls on a holiday or weekend, in which case payment is due on the next work day. If full payment is not received in the office of the Cooperative on or before the date such bill is due, the customer's account will be considered delinquent and subject to disconnection Ln accordance with the rules of the appropriate regulatory authority. Penalty Reference Tariff Section 30.03. SOUTH PLAINS ELECTRIC COOPERATIYB, INC. Tariff for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS .11 DEMAND SIDE MANAGEMENT (DSM) Availability Section Sheet No. 20 1 29 Revision I Page 1 Pvc PUBLIC UTILITY COR�WISSIOM OF TEXAS STAMP APPROVED ,lU 17 '93 eocKET .11904 CONTROL TARIFF CLERK Available to Customers of the Cooperative participating in the Demand -Side Management program and being served under the following rate schedules 1. Irrigation Service Rates DSH Partticipation,Credit The DSM participation credit Las I. Irrigation Service - Summer Seasons $0.0375 per kWh for the first 200 kWh/hp of usage during the months of June through August DSM Program The following described the applicable DSM Program: Irrigation Service A. Cooperative will interrupt Customer load only during: 1. Months o! June, July, August 2. Days of Monday through Saturday 3. Hours of 12 noon to 10s00 p.m. 8. Cooperative will not interrupt Customer load more than a total of 120 hours during the months of June through August. C. Cooperative will interrupt service to all participating Customers at the same time subject to the Terms and Conditions of Service. D. Program participation is limited to 36,S00 HP. S. Customers requesting service alter June 1 do not quality. F. Program will be effective June 1, 1993. E N SOOTE.PLAINS ELECTRIC OOOPMTIVB, INC. Tarif f for Electric Service SECTION TITLE: RATE SCHEDULES APPLICABLE TO ALL AREAS Sect Lon 20 Revision 1 Sheet No. 30 Page Pl;�l.iC UTILITY CC'.'.Sti S°iC6 OF TEXAS s� 17 '93 trocKa .11904 CONTROL 4-� SAV11F.2 CL iK N Terms and Conditions of Service 1. The Customer will execi4t4'a Demand -Side Management Agreement. 2. The Customer will make a contribution -in -aid -of -construction payment equal to SO♦ of the total cost (including installation labor) of the Demand Management Switch. 3. If the Customer should override or disconnect DSM control during the summer season (June through August) or not comply with the provisions of the Demand Side Management Agreement, the program credits will be terminated=,any credits Previously received by Customer will be repaid to the Cooperative by Customer and the demand management switch removed. Additionally, Customer will pay the Cooperative any additional wholesale power cost resulting from Cooperative's inability to control Customer's demand. 4. Cooperative reserves the right to implement the = control program and the associated customer service interruption and service restoration in a manner that provides maximum reliability for the entire electric distribution. system. Depending upon system load conditions, it is possible that the service to participating Customers may not be switched on or off at exactly the same time. S. Cooperative is not responsible for any loss or damage associated with DSM Program service interruption. , 6 . SOUTH PLAINS ELECTRIC COOPERATIVE, INC. COST OF SERVICE F TABLE OF CONTENTS TESTIMONY, E.L. (JACK) MOSS SECTION A Schedule A-1 Statement of Income and Rate of Retum Schedule A-1.0 Summary Report - Present Rates Schedule A-1.1 Cost of Service Allocation - Rate Base - Present Rates Schedule A-1.2 Cost of Service Allocation - Interest - Present Rates Schedule A-2.0 Summary Report - Proposed Rates Schedule A-2.1 Cost of Service Allocation - Rate Base - Proposed Rates Schedule A-2.2 Cost of Service Allocation - Interest - Proposed Rates SECTION B Schedule B-1.0 Monthly Consumers by Rate Schedule r" Schedule B-2.0 Monthly KWH Sold by Rate Schedule P, Schedule B-3.0 Monthly Base Revenue by Rate Schedule Schedule B-4.0 Monthly PCRF Revenue by Rate Schedule Schedule B-5.0 Monthly Total Revenue by Rate Schedule SECTION C Schedule C-1.0 Summary of Allocation Factors - Present Rates Schedule C-2.0 Summary of Allocation Factors - Proposed Rates Schedule C-3.0 Allocation Factors #1 Through #17 Schedule C-4.0 Energy Allocation Factors Schedule C-5.0 Average and Excess Demand Allocations Schedule C-6.0 Allocation of Ratchet Demand SECTION D Schedule D-1.0 Schedule D-2.0 Allocation of Plant - Present Rates Allocation of Plant - Proposed Rate Schedule D-3.0 Account 364-365 - Overhead Distribution Line Schedule D-4.0 Account 368 - Transformers Schedule D-5.0 Account 369 - Services Schedule D-6.0 Account 370 - Meters SECTION E Schedule E-1.0 Allocation of Operating Revenues - Present Rates Schedule E-2.0 Allocation of Operating Revenues - Proposed Rates 7 F OM SOUTH PLAINS ELECTRIC COOPERATIVE, INC. COST OF SERVICE TABLE OF CONTENTS SECTION F Schedule F-1.0 Allocation of Operating Expenses - Present Rates Schedule F-2.0 Allocation of Operating Expenses - Proposed Rates SECTION G L r Schedule G-1.0 Purchased Power Cost SECTION H Schedule H-1.0 Summary of Components of Expenses Schedule H-2.0 Components of Expenses Schedule H-3.0 Components of Plant Schedule H-4.0 Components of Rate Base I Schedule H-5.0 - Classification SECTION L. Schedule 1-1.0 Proof of Revenue - Present Rates Schedule 1-1.1 Proof of Revenue - Proposed Rates SECTION J Schedule J-1.0 Bill Comparison - Residential - Regular Rate 1 Schedule J-2.0 Bill Comparison - Residential - Space Heat - Separate Meter Schedule J-3.0 Bill Comparison - Residential - Space Heat - Single Meter Schedule J-4.0 Bill Comparison - Residential - Water Heater Schedule J-5.0 Bill Comparison - Residential - Space Heat - Water Heater Schedule J-6.0 Bill Comparison - Irrigation - No Control Schedule J-7.0 Bill Comparison - Irrigation - Anytime Control Schedule J-8.0 Bill Comparison - Irrigation - Control 3 Days Schedule J-9.0 Bill Comparison - Irrigation - Control 2 Days Schedule J-10.0 Bill Comparison - Irrigation - Control 1 Day Schedule J-11.0 Bill Comparison - Large Commercial Schedule J-12.0 Bill Comparison - Cotton Gins Schedule J-13.0 Bill Comparison - Oilfield Primary Schedule J-14.0 Bill Comparison - Lighting i; SECTION K Existing Rate Schedules r p DIRECT TESTIMONY Mr. E. L. Moss Bolinger, Segars, Gilbert & Moss Lubbock, Texas k r 1 Q Please state your name and address. 2 A E. L Moss, my business address is 1623 10th Street, Lubbock, Texas. 3 Q By whom are you employed and what is your position? 4 A I am a partner in the certified public accounting firm of Bolinger, Segars, Gilbert & 5 Moss. I am one of the parties in our firm responsible for the firm's activities before 6 State Regulatory Agencies. My primary areas of activity include financial and rate 7 analysis, long range system planning and various system studies. 8 Q Please briefly summarize your educational and professional background. 9 A I graduated from McMurry College, Abilene, Texas, with a Bachelor of Science Degree, r10 with a specialization in accounting. In January 1959 1 was employed with the same 11 accounting firm with which I am presently associated; I have been a Certified Public 12 Accountant since July, 1961, and have been a partner in the firm since April, 1963. 13 1 am registered as a Certified Public Accountant in Texas and New Mexico, having 14 been awarded Certificate No. 5576 by the Texas State Board of Public Accountancy, 15 and No. 1452 by the New Mexico State Board of Public Accountancy. I am a member 16 of the Texas State Society of Certified Public Accountants and of the American r 17 Institute of Certified Public Accountants. I am currently serving on the Public Utility 18 Accounting Committee of the American Institute of Certified Public Accountants. 19 Q Please describe the involvement of your firm in the utility industry. r a 20 A Our firm is engaged as independent auditor by approximately sixty electric and �" 1 I telephone cooperatives located In Texas, New Mexico, Arizona, Oklahoma and 2 California. We have prepared several Rate Studies and Cost of Service Studies and r i 3 have appeared In rate matters before State Regulatory Commissions in the States of 4 Arizona, Texas, New Mexico, and Oklahoma. r , 5 Q Would you please describe your involvement in the rate filing of South Plains Electric r• 6 Cooperative, Inc. (the Cooperative)? 7 A The firm of Bolinger, Segars, Gilbert & Moss has been retained by the Board of 8 Directors of the Cooperative for the purpose of preparing a filing under the streamlined 9 procedures as set forth in Commission Rules 23.23(c), et seq. The information �- 10 required by this procedure is submitted under separate cover. �- 11 In addition, we have been retained to prepare a Cost of Service Study as prescribed 12 by this same Commission Rule. 13 Q Would you briefly describe the Cost of Service study as submitted? 6 14 A Yes. First, in view of the fact that the total requested increase amounts to an overall r five Commission l 15 increase not to exceed percent of test year revenues, as provided by 16 Rule 23.23(c), certain procedures ordinarily performed in a Cost of Service Study are 17 not included in this study, as follows: 18 (a) Certain adjustments to operating expenses have been made to remove expenses 19 related to legislative advocacy and advertising and contributions in exesss of the 20 maximum 3/10th of 1% allowd in Sub Rule 23.21 (b) (1) (E). 21 (b) No change has been made in the base power cost per KWH from the present 22 rates, as is prescribed by the streamlined rate filing procedure. 23 Q What is the purpose of the Cost of Service Study? 24 A The Cost of Service Study assigns the plant investment and the operating expenses 25 associated with providing service to customer classes. When the revenue requirement 26 for the total system has been identified, the allocations of the plant investment and the 27 operating expenses are used in assigning the total revenue requirement to the 28 customer classes. The three basic types of allocation factors developed for use in the r i. , 2 L, r. 1 Study are demand, customer, and energy allocation factors. ` 2 The plant investment and operating expenses were classified as to demand, energy, 3 or customer related functions and were allocated by the appropriate allocation factor. 4 In cases where plant investment or expenses can be identified directly to a customer r- 5 or class of customers, a direct assignment of the investment or expense is made to 6 the customer or class. 7 The fuel and energycharges from purchased power are energy related expenses and 9 P P 9Y P r8 are allocated by the energy allocation factor. The demand charges from purchased 9 power are demand related expenses and are allocated by a demand factor. O & M basis total investment from the 10 expenses are allocated on the of plant which results r 11 allocations as described above. For example, distribution O & M expense for meters 12 is a function of meter investment, and is assigned by the percentage investment in 13 meters for each class. Depreciation expense for electric plant is assigned on the basis 14 of the total plant investment to each respective class. Cost Service Study. 15 Q Please explain the development of the of 16 A The Cost of Service Study accompanies this testimony and includes Sections A 17 through K I 18 Q Please explain the various sections in the Cost of Service Study. 19 A Section A is a summary of the Cost of Service Study. It shows the rate base, the rate r- i 20 of return, and the operating margins for the total system and for each customer class, r' 21 under the existing rate schedules and under the proposed rate schedules. The 22 schedules also show the relative rates of return and operating TIER ratios for each r23 class, under the existing and proposed rates. 24 Schedules B-1.0 through B-5.0 summarize the basic usage data for each of the rate r 25 schedules and customer classes for the test year, showing the consumers, KWH sold, p"p 26 base revenue, PCRF revenue, and total revenue - by month. l 27 Section C summarizes the allocation factors used In the Cost of Service Study and r28 reflects the development of demand, energy, and consumer allocation factors. �' 3 ^, I Additional allocation factors for plant investment are developed in Section D. 2 Q Please explain the general development of these allocation factors. 3 A Schedules C-1.0 and C-2.0 summarize the allocation factors which were used in the 4 Cost of Service Study under the existing rates and under the proposed rates. n 5 Schedule C-3.0 reflects a description of the allocation factors, and Schedule C-4.0 r. 6 reflects the energy allocation factors. 7 South Plains purchases wholesale power from Southwestern Public Service Company 8 (SPS). The actual CP demand for each month for the South Plains system is not 9 known; therefore, the sum of the monthly KW demand billed by the wholesale power 10 supplier has been adopted as the system CP demand. The NCP -noncoincident 11 peak -for each customer class was established monthly from the billing and usage data 12 of South Plains, and from allocations based on the average and excess demand 13 allocations by month for the test year. These monthly calculations are included in the 14 Cost of Service Study as Schedule C-5.0. 15 The the for the investment, sum of noncoincident peaks was used allocation of plant 16 and the sum of coincident peaks was used to allocate the demand component of 17 wholesale power costs. r18 Q Please explain the remaining sections of the Cost of Service. 19 A Section D shows the allocation of the plant investment to the various customer j l 20 classes. Schedules D-3.0 through D-6.0 show the detail of the allocation of plant by 21 account. 22 Section E shows the allocation of revenue, and Section F reflects the allocation of 23 operating expenses to the customer classes, under the present and proposed rates. 24 Q In reviewing Schedule A 2-0, the resultant rates of return for the classes are not equal 25 to the system average. Please explain how you determined the required rate of return r 8 26 for each class. 27 A The final revenue requirement by class under the proposed rates is a management 28 decision of the manager and the Board of Directors. The factors that they considered !' E, 4 r- 1 include: 2 (1) The cost of service for each class. `s 3 (2) The rate of return generated by the respective class during the test year. 4 (3) The maximum Increase provided for a specific customer class by Commission 5 Rule 23.23(c). r 6 In view of the above considerations, the following decisions were made: 7 Q In summary, what are the amounts' and percentages of increase proposed to the 8 respective classes? 1 9 A 1) Classes which are yielding a return greater than the system average - General 10 Service, Schools and Churches - Large, and Oilfield Secondary -were not increased. 11 2) The Irrigation Class was increased by 6.05%. ` 12 3) The remaining Classes were increased the maximum amount allowable under r 13 Rule 23.23(c). 14 Q In summary, what are the amounts' and percentages of increase proposed to the r 15 respective classes? 16 A Residential - An increase of $523,443, or 5.85%; Irrigation - an increase of $166,188, 17 or 6.05%; Large Power - an increase of $159,662, or 6.37%; Cotton Gins - an increase a. 18 of $24,494, or 4.64%; Oilfield Primary - an increase of $8,687, or $2.77%; Lighting - an 19 Increase of $36,559, or 7.57%. i 20 Q What are the effects on the respective rates of return of the customer classes? 21 A The rate of return on rate base for the Residential Class increases from .09% to 22 3.70%; Large Power increases from 2.44% to 6.71 %; Cotton Gins increases from 23 1.83% to 4.65%; Oil Field Primary increases from 4.65% to 6.92%; and Lighting 24 increases from 1.16% to 3.30%. All of these classes were increased by the maximum 25 amount allowable under Commission Rule 23.23(c). P' 26 The Irrigation rate of return increases from (6.52%) to (4.78%). The Irrigation rate was w 27 increased by an amount less than the maximal allowable amount; the percentage in 7, 28 crease Total Revenue amounts to 6.05%. This increase Is proposed in view of the i 5 6 1 abnormal conditions surrounding the irrigation load during the test year, as well as the 2 present state of the agricultural economy in the service area of South Plains. l l 3 Q Have you made any attempt to quantify the results of irrigation operations under 4 normal conditions, and an estimate of the rate of return under these conditions? r- 5 A Yes. When a normalization is made of the Irrigation Sales and corresponding cost of r. 6 power, the return from irrigation under the proposed rates amounts to 3.87%, which 7 is more commensurate with the return realized from the residential category, as r 8 reflected above. The normalization is necessary because of the fact that during the 9 spring and early summer of 1992 the weather in the West Texas area was extremely 10 inclimate, ranging from extremely heavy rainfall to abnormally cold temperatures. 11 These conditions persisted until mid -June, resulting in an extremely low acreage of 12 Cotton planting that survived. P g 13 This resulted in irrigation sales of the cooperative amounting to slightly over 36 million 14 KWH, as compared to normal sales of approximately 70 million KWH. 15 In to more Irrigation order provide an estimate of operations under normal conditions, 16 we have done the following: ° 17 1) Through an analysis of KWH sales in more normal years, on the basis of 70 f 18 million KWH sales we have estimated the sales at the various usage levels, for the 19 controlled and non -controlled classes. KWH 20 2) These sales have been applied to the proposed ratios to determine the 21 revenue generated by these KWH sales at the proposed rates. 22 3) The cost of power applicable to the additional KWH sales and purchases has r- 23 been estimated. For purposes of this estimate it was assumed that the additional 24 KWH sales/purchases should have not produced any additional ratchet cost. The r 6 25 basis for this assumption is the fact that the annual peak for the test year was 104,096 26 KW, as reflected by COS Schedule G-1.0. This peak for the previous year (when 27 irrigation KWH sales amounted to an abnormal 93 Million KWH) was 115,025 KW. r- t, 28 See Schedules ELM-1 and ELM-2 attached to this testimony. r } 6 F 1 Section J contains billing comparisons which show the impact upon customers at 2 various usage levels. These billing comparisons assume the PCRF level for both the r3 existing and proposed rates as was experienced during the test year by the i. 4 Cooperative. 5 RATE DESIGN 6 Q What were the basic goals underlying the rate design of the proposed rates? 7 A The proposed rates were designed to do the following: 8 (1) Reflect the cost components as developed in the Cost of Service Study, in so far 9 as possible. Changes 10 (2) Reflect the rates that include the power cost of the test year. in the total r 11 base power cost above or below that experienced during the test year will be passed 12 through to the consumer by a monthly PCRF factor. r13 (3) Insure that the rate of return and margin as a percent of revenues by class under 14 the proposed rates are fair and reasonable In terms of the overall requested margin. Ir— l 15 (4) Consider consumer impact. 16 Q How have these items been reflected in the proposed rate schedules? 17 A 1) For the Residential Class the proposed increase is reflected in the energy charge 18 at approximately $.0035 per KWH. The effect of this proposed increase at various 19 usage levels and with various equipment employed by the consumer is reflected on 20 Schedules J-1.0 through J-5.0. 21 2) For the. Irrigation Class the increase is reflected in the energy charge in excess 22 of the first 200 KWH per horse power. y 23 The present irrigation rate provides for load control credits for the first 200 KWH per 24 horse power ranging from $.06 per KWH for the anytime control consumer to $.0125 25 per KWH for the one day control consumer. Under the proposed rate, all load control t" 26 credits are at $.0375 per KWH. This is allowance tracts the net savings realized by the 27 cooperative in its power bill as a result of the load control program. Attached to this r 28 testimony is Schedule ELM-3 detailing the calculation of net savings and the credit �" 7 �-- 1 factor. The effect of the proposed increase at various usage levels and under the ` 2 various load control situations, is reflected on Schedule J-6.0 through J-10.0. 3 3) As has been previously mentioned on page 5 of this testimony, the Schools and 4 Churches - Large Classification is yielding a rate of return which is in excess of the 5 system average. For this reason, we propose no change in rate or rate design for this 6 class, and the present Large Power rate will continue to apply. 7 For the Large Commercial Class, an increase in the customer charge from $28 to $50 8 has been proposed. This increase more closely reflects the cost per customer of 9 rendering service to the Large Commercial Class. Additionally, a change in rate r 10 design is proposed. The present rate provides for a customer charge, demand I^ 11 charge, and a flat energy charge. The proposed rate also provides for these same 12 components. The energy charge as proposed consists of a charge of $.06519 per 13 KWH for the first 200 KWH per KW, and $.035 per KWH for the remaining KWH. The 14 purpose of this proposed rate is to provide a rate which is more sensitive to the 15 consumer's load factor, and to more closely match the power cost of South Plains. 16 Under such an arrangement, the greater the load factor (and the efficiency of the load) 17 the lower the cost of energy per KWH. The proposed rate the consumer tracks that 18 same pattern. The effects of the usage at various levels, and at various load factors 19 is reflected on Schedule J-11.0. 20 4) An increase is proposed customer charge for the Cotton Gin rate from $28 to $50. 21 This increase more closely tracts the customer cost providing service to the cotton i 22 gins. A slight increase is also proposed in the KWH charge. The effect of usage at 23 various levels, and at various load factors is reflected on Schedule J-12.0. r24 5) For the Oil Feld Primary, the customer charge is increased from $28 to $50. No 25 change is proposed in the demand charge, and a slight increase in the energy charge 26 is proposed. The effect of usage at various levels is reflected on Schedule J-13.0. t. r 27 6) The present Security Lighting is classified as to 6,000 and 12,000 lumens. In the 28 proposed rates, a refinement of this classification into Mercury Vapor and High r' 8 `. 1 Pressure Sodium Categories has been done, in order to more accurately account for f 2 the revenue and energy usage of this class. In addition, the Cooperative has had 3 requests for 175 Watt, 400 Watt and 1,000 Watt Halide lights, which are currently not 4 offered. The 175 Watt and 400 Watt Halide lights have been priced at the same rate 5 the 175 Watt and 400 Watt Mercury Vapor lights, 1,000 Watt as respectively. The *• 6 Halide light has been priced at $17.50 per month. An analysis of revenue at present P 7 and proposed rates is reflected on Schedule J-14.0. t 8 As the schedules mentioned above reflect, the Increases as proposed are equitable 9 and are not unduly burdensome on any rate class. 10 Q Does this testimony? conclude your 11 A Yes, it does. f R 9 r SOUTH PLAINS ELECTRIC COOPERATIVE, INC. IRRIGATION ANNUALIZATION Schedule ELM-1 Normal KWH Sales 70,000,000 Irrigation KWH Sales — Test Year 36,001,843 33,998,157 Return realized from Irrigation for the year ended September 30, 1992 (Test Year) at present rates amounts to ($621,159) — see COS Schedule A-1.0. The return at proposed rates amounts to ($455,565) — See COS Schedule A-2.0. The results of irrigation sales of 70 Million KWH Is estimated as follows: Return — Proposed Rates — on Test Year Sales $ (455,465) Additional Revenue Per Schedule ELM-2 $ 4,993,356 Per COS Schedule 1-1.1 2,912,883 2,080,473 Estimated Power Cost Adjustment: Power Cost Test Year — COS Schedule F-1.0, page 3 of 3 $ 1,803,923 Less: Ratchet Cost — COS Schedule F-1.0, page 2 of 3 476,248 Cost of Power, Less Ratchet $ 1,328,676 Per KWH (= 36,001,843) $ 0.036906 Additional KWH 33,998,157 Additional Power Cost 1,254,736 Adjusted Return — after Normalization $_ 370,242 Normalized Return on Rate Base: Rate Base — per COS ScheduleA-2.0 $ 9,531,691 Add: 12/365 x $1,254,736 41,251 Adjusted Rate Base $ 9,572,942 Adjusted Return on Rate Base 3.87% fe— 1 j SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE — IRRIGATION Schedule ELM-2 YEAR ENDED SEPTEMBER 30, 1992 BILLING UNITS RATE REVENUE IRRIGATION NON —CONTROLLED 47,598 Total Bills Energy Charge July —Sept. 1st 200 Kwh per HP 7,936,287 $0.13642 1,082,668 Remaining Kwh 9,283,517 $0.07845 728,292 Oct. -June All Kwh 27,753,322 $0.07150 1,984,363 Annual Minimums 55,970 PCRF Revenue 44,973,126 ($0.012788) (575,116) Subtotal $3,276,176 CONTROL ANYTIME Total Bills 17,700 r' Energy Charge July —Sept. 1 st 200 Kwh per HP 7,308,003 $0.13642 $996,958 Remaining Kwh 5,219,226 $0.07E45 409,448 Oct. —June All Kwh 12,499,646 $0.07150 893,725 PCRF Revenue 25,026,874 ($0.012788) (320,044) Annual Minimums 11,143 Load Management Credits 7,308,003 ($0.0375) (274,050) Subtotal $1,717,180 TOTAL IRRIGATION 70,000,000 $4,993,356 i r l l Schedule ELM-3 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. The Load Management agreement between SPS and SPEC for the year ended 9-30-92 resulted in the following: Plant investment by SPEC $ 378,750 TID permitted by SPS 9,300 Power Cost savings to SPEC — per SPEC records Cost of Program O & M Expenses Depreciation Interest Taxes Net Savings to SPEC Connected Horsepower Savings per Horsepower % of Investment $ 31,000 6.0% 22,725 6.5% 24,620 1.0% 3,790 $ 354,937 82,135 $ 272,802 36,510 $ 7.47 (*) Note: Connected Horsepower limited to approximately 36,500 H.P. based on the Target Interruptible Demand (TID) of 9,300 kW as specified by Southwestern Public Service Company in its DSM Rate Rider. The load management credit of $.0375 is derived by dividing the savings per horsepower or $7.50 by 200 KWH per horsepower r f 6 f AFFIDAVIT ` THE STATE OF TEXAS § COUNTY OF LUBBOCK § is r Before me, the undersigned notary public, personally appeared E.L. MOSS, who being by me 4 first duly sworn on oath deposes and says that the foregoing prepared direct testimony and rstatement of fact contained therein are true and correct to the best of his knowledge and belief. E.L. MOSS Subscribed and sworn before me thiswlay of , 1993 to certify which witness my hand and official sea] of office. My Commission expires -5 " -1 _ q r^.rr.,rs�..o�.rr�.rr�v.�✓rrrrrrrr�� Linda Crump NOTARY PUBLIC State of Texas �. . , MY Commission Expires 5.9.94 F49W®R" � ... - 10 EXHIBIT ELM-1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. STATEMENT OF INCOME YEAR ENDED SEPTEMBER 30, 1992 OPERATING REVENUES: Base Revenue PCRF Revenue Other Revenue Total Operating Revenues OPERATING EXPENSES: Purchased Power Transmission Distribution — Operation Distribution — Maintenance Consumer Accounts Customer Service and Informational Administrative and General Depreciation Taxes Other Interest & Deductions Total Operating Expenses OPERATING MARGINS — Before Fixed Charges FIXED CHARGES: Interest on Long Term Debt OPERATING MARGINS — After Fixed Charges Other Non —Operating Margins Other Capital Credits NET OPERATING MARGINS NONOPERATING MARGINS: Interest and Investment Income NET MARGINS (LOSS) TIER Net Modred Operating RATE BASE Return on Rate Base COSA-[ Actual Proposed Test Year Increase Test Year $ 24,870,823 $ 924,053 $ 25,794,876 (4,488,127) (4,488,127) 127,704 127,704 $ 20,510,400 $ 924,053 $ 21,434,453 $ 13,386,267 $ $ 13,386,267 2,205 2,205 850,314 850,314 1,015,166 1,015,166 860,768 860,768 122,010 122,010 1,778,214 (4,821) 1,773,393 1,784,182 1,784,182 621,283 621,283 61,254 61,254 $ 20,481,663 $ (4,821) $ 20,476,842 $ 28,737 $ 928,874 $ 957,611 $ 1,354,929 $ $ 1,354,929 $ (1,326,192) $ 928,874 $ (397,318) (15,167) (15,167) 174,781 174,781 $ (1,166,578) $ 928,874 $ (237,704) t. fGn Inn C @ 4an Inn C996 876 $ 928,874 $ (68,002) 0.26 0.95 0.14 0.82 0.02 0.71 $38,354,181 $38,354,181 0.07% 2.50% i r, SOUTH PLAINS ELECTRIC COOPERATIVE, INC. EXPENSE ELIMINATIONS TEST YEAR ENDED SEPTEMBER 30, 1992 LEGISLATIVE ADVOCACY r L, 7 NRECA DUES i TEC DUES r- f l 4 AMOUNT % 21,003 0.200% 42.01 16,526 7.790% 1287.38 ADVERTISING AND CONTRIBUTIONS IN EXCESS OF 3/10TH OF 1% i TOTAL REVENUE 20.510.400 ACTUAL ADVERTISING, DUES & CONTRIBUTIONS ADVERTISING r j DUES(37529-1329) ` CONTRIBUTIONS r L AMOUNT IN EXCESS r" 1 TOTAL ELIMINATIONS t f: 61631.20 9,343.00 36,200.00 19.480.00 65,023.00 1 V C-0. V V 3,491.80 4,821.18 South Plains Electric Cooperative, Inc. test Year Ended September 30. 1992 Present Rates SUMMARY REPORT ACCOUNT ---------------- ---------- TOTAL DOLLARS -------------------------- RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG -------------------------- LG POWER Gins Oilfield Sec Oilfield Pri ------------- Lighting RATE BASE 30.346.182 14.439,931 ------------- 9,532.006 ------------- 2,904,509 811002 ------------- 3.727,282 1,048.409 ------------- 3,788,092 ------------- 386,033 1.708,918 OPERATING REVENUES 20,510,400 9,007.790 2,163.298 1.660.714 468,633 2.521.942 639.426 2.646.856 315.879 485,863 OPERATING EXPENSES 20.481.663 -------------------------- 81995.169 3.384.458 ------------- 1.479.204 410.273 ------------- 2,430,979 620.209 2.397.698 297.915 465.759 RETURN 29.737 12.621 ------------- -621.159 ------------- 161.510 58.360 ------------- 90.963 19,217 -----=------- 2494158 -------------------------- 17,963 20.105 RATE OF RETURN 0.075% 0.0871 -6.517% 6.249% 7.196% 2.4407. 1.833% 6.577% 4.653% 1.176% RELATIVE ROR 1.000 1.166 -86.956 83.389 96.023 32.565 24.459 87.769 62.090 15.698 INTEREST 1454.929 ------------- 508,494 337,976 103.018 18,731 131,291 37,088 133,607 13.545 61.169 OPERATING MARGINS ------------- -1,326,192 -495,673 -------------------------- -959,135 -------------------------- 78,483 29.629 ------------- -40,329 -17,871 ------------- 115,551 -------------------------- 4.418 -41.064 MARGINS 7. OF REVENUE -6.466% -5.5051 -34.710% 4.726% 6.322% -1.599Z -2.795% 4.366% 1.399% -8.452% OPERATING TIER 0.021 0.025 -1.836 1.762 2.031 0.693 0.518 1.065 1.326 0.329 REVENUE DEFICIENCIES UNIFORM ROR = 2.484706 924.053 346.169 858,002 -109.342 -38.209 1.649 6,633 -155.035 -8.371 22.357 REV DEF AS Z REV 4.5051 3.843% 31.0507. -6.584% -8.153Z 0.0651 1.069% -5.8577. -2.6501 4.602% UNIFORM Z MAR =-1.976134 924.053 3201.855 890,583 -107,621 -37.714 -6.858 5,767 -162.167 -10.153 31,360 REV DEF AS Z REV 4.505% 3.562% 32.229% -6.480% -8.048% -0.2721 0.902% -6.127% -3.2141 6.455Z cn cMI) 0 Co sC/) m c rD a South Plains Electric Cooperative. Inc. Test Year Ended September 30, 1992 Present Rates COST OF SERVICE ALLOCATION - RATE BASE ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH & CH LG ------------- LG POWER Gins Oilfield Sec Oilfield Pri ------------- Lighting -------------------- PLANT IN SERVICE ------------- 57,665.476 ---- 107 -------------------------- 21,628.690 14.416.713 ------------- 4.387.980 1.220.886 -------------------------- 5,574,650 1.576.414 ------------- 5,674.571 ------------- 575,727 2.609.845 ACCUM DEPR TRANS -960.169 101 -424.412 -75.563 -57,199 -29.994 -158.951 -36.649 -153.598 -13.322 -10.492 ACCUM DEPR DIST -18.597,749 104 -6.926.097 -4.775,939 -1,427.362 -386.322 -1.747.072 -500.420 -1,784,697 -182.809 -867,033 ACCUM DEPR GEN -1.777.954 106 -662.138 -456.582 -136.457 -36.933 -167,021 -47.040 -170.618 -17.476 -62.899 ------------- ------------- -------------------------- ------------- ------------- --- ---------- NET PLANT 36.329.604 1274 13.616.042 9,108,629 2.766.963 767,637 3.501,606 991.506 3.565.669 362.121 1,649.431 37.4791 25.072% 7.616% 2.113% 9.6381 2.7291 9.815% 0.997% 4.540% MATLS & SUFPLIES 977.850 104 364.167 251.114 75.049 20.312 91.859 26.312 93.837 9.612 45.588 PREPAYMENTS 180,072 119 74.910 39.180 17.253 2,681 16.949 3,055 19.909 1.928 5.308 CASH WK CAP POWER 440.096 122 201,490 59,307 27.676 9,565 51.834 15,685 53.856 7.337 7.346 CASH NK CAP OEN 596.241 120 256.958 91,374 31,147 14,639 79,750 17,076 76.463 7.617 5.218 GIST REPS -167,681 108 -73.630 -22.597 -13,579 -3,832 -20.617 -5.224 -21.641 -2.581 -3.972 TOTAL _____________ _____---_=___ _____==_--_== =__-_____=___ -__________-= ====-_======_ RATE BASE 38.346.182 1281 14.439.931 9.532.006 2.904,509 811.002 3.727.282 1.048.409 3.780,092 396.033 1.708.9le 37.6571 24.850% 7.574% 2.1151 9.7201 2.734% 9.9795 1.007% 4.457% South Plains Electric Cooperative, Inc. Test Year Ended September 30. 1992 Present Rates COST OF SERVICE ALLOCATION - INTEREST ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH b CH LG LG POWER Gins Oilfield Set Oilfield.Fri Lighting -------------------- INTEREST LSD ------------- ---- 1.354.929 105 -------------------------- 508.494 337.976 ------------- 103.029 -------------------------- 28.731 ------------- 131,291 37.008 ------------- 133.607 -------------------------- 13.545 61.169 TOTAL INTEREST 1.354.929 1291 508.494 337.976 103.028 28.731 131.291 37.008 133.607 13.545 61.169 3?.5297, 24.4441 7.6047. 2.121% 9.690% 2.737% 9.861% 1.000% 4.5157 ��i South Plains Electric C000erative. Inc. lest Year Ended SeotenDer 30, 19Y2 Proposed Rates SUMMARY REPORT ACCOUNT TOTAL DOLLARS RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oilfield Set Oilfield Fri ------------- Lighting -------------------------- RAIE BASE ------------- 38,346.182 -------------------------- 14,439.038 9,531.691 -------------------------- 2,905,077 ------------- 811.162 ------------- 3.726.931 1.048.403 ------------- 3.788,997 ------------- 386,075 11708.807 OPERATING REVENUES 21.434.452 9.531.233 2,929.466 1.660.714 466.633 2,681.624 660.920 2.646,656 324.565 522.421 OPERATING EXPENSES 20.461.663 8.996.473 31394.951 1.479.371 410.037 21431.492 620.203 2,396.364 297.840 ------------- 465.924 ;ETURN ------------- 952,189 -------------------------- 534.759 -455.465 -------------------------- 182.343 ------------- 58.597 ------------- 250.132 48,717 ------------- 250.492 ------------- 26.717 56.497 ;ATE OF RETURN 2.465 3.704% -4.779% 6.277% 1.224% 6,711% 4,647% 6.6111 61920% 3.306% ELATIVE POP, 1.00(1 1.491 -1.923 2.526 21907 2.101 1.810 2.661 21185 1.531 INTEREST 1.354.929 5QB.494 337.976 103.026 29.731 131.291 37.088 133.607 13.545 ------------- 61.169 OPERATING MARGINS ------------- -402.140 -------------------------- 26.265 -793.441 -------------------------- 79.316 ------------- 29.965 ------------- 118.840 11.628 ------------- 116.985 ------------- 13.172 -4.671 MARGINS X OF REVENUE -1.876% 0.276% -27.0951 4.776% 6.373% 4.432% 1.138% 4.416i 4.058% -U.8947. OPERATING TIER u.10.3 1.052 -1.34N 1.170 2.039 11905 1.114 1.815 1.972 0.924 REVENUE DEFICIENCIES UNIFORM FOR = 2.484706 1 -I/M92 692.299 -110.161 -s8.442 -157,529 -Z2,667 -156.347 -17,124 -14,039 REV DEF AS 1 REV U.4Ui)': -1.846% 23.02% -6.633% -6.203% -5.8741 -3.399% -5.907% -5.276% -1.681% UNIFORM X MAR =-1.876134 1 -201.307 724.880 -108.438 -37.945 -166.036 -23,733 -163.477 -18.906 -5.036 REV DEF AS % REV 0.000. -2.1121 24.744% -6.530% -8.097% -6.192% -3.548t -6.176% -518251 -0.9641, (n c-) 0 O S Cn fD G. C CD D N South Plains Electric L000erative, Inc. lest Year Ended Seotember 30. 1992 Pr000sed Rates COST OF SERVICE ALLOCATION - RATE BASE ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. ---- RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oiliield Sec Oilfield Pri ------------- Lighting PLANT IN SERVICE 57.665.476 107 -------------------------- 21.628,690 14,416,713 ------------- 4,387,980 -------------------------- 1.220.886 ------------- 5,574.650 1..576,414 ------------- 5,674,571 ------------- 575.727 21.609,945 ACCUM DEPR TRANS -960.169 01 -424,412 -/5.563 -57498 -29,994 -158951 -36.648 -153.588 -13.322 -10,492 ACCUM DEPR DIST -18.597.749 104 -6,926.097 -4.775.939 -1.427.362 -396.322 -1.747:072 -500.420 -1,784,697 -182.908 -867.033 ACCUM DEPR GEN -1,771,954 106 -662.136 -456.562 -136.457 -36.933 -167,021 -47,840 -170,618 -17.476 -82,869 Subtotal------------- -------------------------- ------------- -------------------------- ------------- ------------- ---------------------- -- NET PLANT 36,329.604 1211 13.616.042 94 0U.629 2.766,963 767,637 3.501.606 Y91,506 3.565,668 362.121 1.649.431 37.479x 25.072% 7.616% 1.113Y 9.6387. 2.729% 9.8152 0.997% 4,540X MAILS 4 SUPPLIES 977,950 104 364.167 251.114 75.049 20.312 91.859 26.312 93.837 9.612 45,589 PREPAYMENTS 180.072 119 ?4.944 39.193 17.232 2.675 16.861 3.055 19,875 1,926 5,312 CASH WK CAP POWER 440.096 122 201,490 59.307 27.676 9.565 57.834 15,685 53.056 7.337 7,346 CASH WK CAP O&M 586.241 120 256,956 97.374 31.147 14.639 79,750 17.076 76.463 7.617 5,218 COST DEFS -167,681 108 -74.564 -22.925 -12.990 -3,665 -20,979 -5,230 -20.702 -2.538 -4.08u TOTAL=__°=_____=__ -------------------------- ------------- ------------- =______=_---=-__==-_____=_ RATE BASE 38.346.192 1281 14.439.039 9.531.691 2,905.077 811.162 3.726.932 11048.403 3.788,997 386.075 1.708.607 37.654% 24.857% 1.576% 2.115I 9.719% 2,734% 9.881% 1.007% 4.456% I.- South Plains Electric Cooperative, Inc, Test Year Ended Seotember SO. 1992 Pr000sed Rates COST OF SERVICE ALLOCATION - INTEREST ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POOER Gins Oilfield Sec Oilfield Pri Lighting -------------------- INTEk ST LTD ------------- ---- 1.354.929 105 ------------- 508,494 ------------- 337.976 ------------- 103.028 ------------- 28,731 ------------- 131.291 ------------- S7,088 ------------- 133.607 -------------------------- 13,545 61.164 TOTAL- -- - ---- - - --- -- - -- -- - - - --- - -- - - - ----------- (NIEREST 1.354.929 1291 508,04 337,976 103.028 28,731 131.291 37,088 133.607 13.545 61.169 37.529i. 24.944% 1.6041 2.121% 9.690% Z.1371 Y.0611 1.000% 4.515% C/N C7 n C1 S CA M n. G M n N i r COS Schedule B-1.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. r MONTHLY CONSUMERS BY RATE SCHEDULE JAN 92 FEB MAR APR MAY JUN JULY RESIDENTIAL 16,188 15,758 16,675 15,851 15,902 16,293 16276 IRRIGATION 5,492 5,531 5,385 5,329 5,313 5,499 5318 GEN SVC 1,593 1,555 1,592 1,604 11609 1,589 1630 SCH & CH SMALL 39 39 40 41 42 43 43 SCH & CH LARGE 26 26 24 24 26 26 26 LARGE POWER 112 110 105 106 116 116 119 GINS 20 20 20 19 18 19 19 OILFIELD SECDRY 913 904 897 912 690 910 880 7 OILFIELD PRI 21 21 23 26 20 19 20 w LIGHTING 6,950 6,953 6,993 7,051 7,094 7,114 7171 TOTALS 31,354 30,917 31,754 30,963 31,030 31,628 31.502 AUG SEP OCT 91 NOV DEC TOTAL RESIDENTIAL 16,121 16,434 16,029 15,977 16,049 193,553 rIRRIGATION 5,397 5,544 5,522 5,517 5,475 65,322 GEN SVC 1,626 1,627 1,531 1,604 1,586 19,146 r� i SCH & CH SMALL 42 39 38 39 41 486 SCH & CH LARGE 26 24 24 24 26 302 LARGE POWER 117 119 113 119 112 1,364 GINS 18 18 20 20 20 231 OILFIELD SECDRY 878 882 899 904 889 10,758 OILFIELD PRI _ 23 21 21 21 21 257 LIGHTING 7,191 7,225 6,740 6,831 6,917 84,230 TOTALS 31,439 31,933 30,937 31,056 31,136 375,649 r• COSB1A r I I r F RESIDENTIAL IRRIGATION GEN SVC SCH & CH SMALL SCH & CH LARGE LARGE POWER GINS OILFIELD SECDRY OILFIELD PRI LIGHTING TOTALS RESIDENTIAL !� IRRIGATION i GEN SVC SCH & CH SMALL SCH & CH LARGE LARGE POWER GINS OILFIELD SECDRY OILFIELD PRI LIGHTING TOTALS COSB2.0 COS Schedule B-2.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. MONTHLY K1NH SOLD BY RATE SCHEDULE AN 92 FEB MAR APR MAY JUN JULY 14,487,678 11,586,770 10,206,952 9,767.477 10,915,981 12,017,235 15,538.017 123,412 50,126 118,565 2,695,759 4.276,184 538,514 2,854,003 2,027,993 1,591,427 1,564,659 1,531,708 1,776,623 1,768,955 1,991,082 59,037 54,172 55,881 52,619 57,933 65,751 55,416 547,920 467,220 464,827 447.428 569,000 578,700 427,520 3,735,117 2.939,240 2,571,989 2,780,190 3,592,600 3,524,285 3,493,209 3,888,800 1,354,240 254,400 54,720 15,680 12,800 28,320 3,506,572 2,871,254 2,978,849 3,371,842 3,339,630 3,223,104 2,844,434 589,310 435,081 921,575 993,356 510,838 469,760 454119 581,123 577,503 577,728 584,655 586,631 588,389 587,269 29,546,962 21,927,063 19,715,425 22,279,754 25,641,300 22,787,493 28,273,389 AUG SEP OCT 91 NOV DEC TOTAL 16,054,204 14,608,180 12,154,866 9,880,647 12,153,196 149,371,203 13,768,525 10,405,729 495,199 437,721 238,106 36,001,843 2,028,191 1,981,817 1,747,391 1,516,218 1,805,248 21,331,312 54,878 67,661 69,884 51,025 61,437 705,694 426,820 672,440 712,760 544,160 531,100 6,389,895 3,476,830 3,586,412 3,838,536 3,394,411 3,552.352 40,485,371 100,230 21,840 267,590 817,580 5,883,380 12,699,580 2,905,789 3,126,403 2,796,581 3,058,111 3,051.715 37.074,314 347,881 452,660 548,066 438,030 516,415 6,677,091 588,459 595,886 559,182 565,186 574,542 6,966,553 39,751,807 35,519,028 23,190,055 20,703,089 28,367,491 317,702,856 r pm COS Schedule B-3.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. MONTHLY BASE REVENUE BY RATE SCHEDULE JAN 92 FEB MAR APR MAY JUN JULY RESIDENTIAL 1,018,830 828,975 756,334 733,979 831,933 907,649 1.149.402 IRRIGATION 6,771 (5,873) 12,039 180,678 264,667 36,050 201,337 r� GEN SVC 176,478 143,822 142,595 140.690 158,927 158,457 174.959 SCH & CH SMALL 5,021 4,670 4,808 4,589 5,006 5,588 4,B30 r- SCH & CH LARGE 44,127 40,441 41,910 41,544 50,477 51,113 37,204 4 LARGE POWER 275,734 234,312 198,472 210,173 271,787 269,004 266,069 GINS 248,223 102,555 18,795 8,742 2,935 3,563 4,880 I OILFIELD SECDRY 281,118 254,769 261,063 278,799 277,065 263,960 251,902 OILFIELD PRI 32,303 25,716 66,016 69,061 29,146 27,206 26.657 LIGHTING 48,305 48,269 0,341 48,810 *,160 49,295 49,347 rTOTALS 2,136,910 1,677,656 1.550.373 1.717.065 1.961,103 1,771,885 2,166,587 rAUG SEP OCT91 NOV DEC TOTAL RESIDENTIAL 1,184,861 1,086,232 916,257 745,204 874,642 11,034,498 t t IRRIGATION 1,392,579 918,538 32,491 29,216 118,739 3,207.232 GEN SVC 177,614 174,248 155,356 139,590 160,193 1,902,929 SCH & CH SMALL 4,774 5,657 5,800 4,439 5,231 60,413 SCH & CH LARGE 37,737 59,955 61,740 50,672 44,177 561,097 111 LARGE POWER 264,842 275,222 290,462 263,983 270,654 3,090.714 GINS 8,674 3,070 24,641 73,324 354,528 853,930 OILFIELD SECDRY 254,849 265,451 251.528 262,304 263,708 3,166,516 OILFIELD PRI 21,273 26,295 31,024 25,343 29,659 410,699 I f LIGHTING 49,390 49,929 46,814 47,306 47,830 582,796 TOTALS 3,396,593 2,864,597 1,816,113 1,642,381 2,169,561 24,870,824 I Cos Schedule B-4.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. MONTHLY PCRF REVENUE BY RATE SCHEDULE b � JAN 92 FEB MAR APR MAY JUN JULY RESIDENTIAL (204.432) (162,793) (143,679) (137,585) (159,604) (171,373) (20,534) IRRIGATION (1,742) (714) (1,609) (37,939) (62,578) (7,676) (3,772) GEN SVC (28,604) (22,358) (22.026) (21,578) (25,980) (25,227) (2,624) SCH & CH SMALL (834) (761) (787) (741) (847) (938) (73) SCH & CH LARGE (7,738) (6.564) (6,544) (6,302) (8,319) (8,253) (565) LARGE POWER (52.748) (41,291) (36.206) (39,162) (52.530) (50,259) (4,617) GINS (54,918) (19,027) (3,581) (771) (229) (183) (37) ` OILFIELD SECDRY (49,520) (40,342) (41,933) (47,496) (48,828) (45,965) (3,759) OILFIELD PRI (8,322) (6,113) (12.973) (13,992) (7,469) (6.699) (600) LIGHTING (8,207) (8,113) (8,133) (8,235) (8,5M (8,391) (776) TOTALS (417,065) _ (308.0761 (277.471) (313,8011 (374,9611 (324,964) (37,357) AUG SEP OCT 91 NOV DEC TOTAL RESIDENTIAL (144,685) (277,873) (224,919) (192.204) (243,687) (2,083,368) r l IRRIGATION (124,085) (197,935) (9,232) (8,579) (4,541) (460,402) GEN SVC (18,279) (37,697) (32,159) (29,692) (36,197) (302,421) SCH & CH SMALL (495) (1,287) (1,293) (993) (1,232) (10,281) SCH & CH LARGE (3,847) (12,791) (13.188) (10,585) (10,649) (95.345) E LARGE POWER (31.334) (68.220) (71,021) (66,027) (71,228) (584,643) GINS (903) (415) (4,951) (15,904) (117,968) (218,887) OILFIELD SECDRY (26.188) (59.470) (51,742) 09,486) (61,190) (535,919) OILFIELD PRI (3,135) (8,610) (10,140) (8,521) (10,355) (96.929) t LIGHTING (5,304) (11,335) (10,346) (10,993) (11.520) (99,930) TOTALS (358,255) (675,633) (428,991) (402,984� (568,567) (4,488,125) i COSB4A ti 1 i 7, RESIDENTIAL IRRIGATION GEN SVC SCH & CH SMALL SCH & CH LARGE LARGE POWER GINS OILFIELD SECDRY OILFIELD PRI LIGHTING TOTALS RESIDENTIAL rIRRIGATION GEN SVC SCH & CH SMALL SCH & CH LARGE LARGE POWER GINS OILFIELD SECDRY OILFIELD PRI LIGHTING TOTALS r COMA COS Schedule B-5.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. MONTHLY TOTAL REVENUE BY RATE SCHEDULE JAN 92 FEB MAR APR MAY JUN JULY 814,398 666,162 612,655 596,394 672,329 736,276 1,128,868 5,029 (6,5M 10,430 142,739 222,089 28,374 197,565 147,874 121,464 120,569 119,112 132,947 133,230 172,335 4,187 3,909 4,021 3,848 4,159 4,650 4,757 36,389 33,877 35,366 35,242 42,158 42,860 36,639 222,986 193,021 162,266 171,011 219,257 218,745 261.452 193,305 83,528 15,214 7,971 2,706 3,380 4,843 231,598 214,427 219,130 231,303 228,237 217,995 248.143 23,981 19,603 53,043 55,069 21,677 20,507 26,057 40,098 40,156 40,208 40,575 40,583 40,904 48,571 1,719,845 1,369,580 1,272,902 1,403,264 1,586,142 1.446,921 2,129,230 AUG SEP OCT 91 NOV DEC TOTAL 1,040,176 808,359 691,338 553,000 631,155 8,951,130 1,268,494 720,603 23,259 20,637 114,198 2.746,830 159,335 136,551 123,197 109,898 123,996 1,600,508 4,279 4,370 4,507 a 3,446 3,999 50,132 33,890 47,164 48,552 40,087 33,528 465,752 233,508 207,002 219,441 197,956 199,426 2,506,071 7,771 2,655 19,690 57,420 236,560 635,043 228,661 205,981 199,786 202,818 202,518 2,630,597 18,138 17,685 20.884 17,822 19,304 313770 44,086 38,594 36,468 36,313 36,310 482,866 3,038,338 21188.964 1.387,122 11239.397 1,600,994 20,382,699 __ r�TlTl 7--1 7--1 -- with, Elect, ,L000eraL,vr. Inc�� Test tear Ended SeDteeber 30, 1992 Present Rates ALLOCATION FACTORS A.F. FACTOR TOTAL PERCENT RESIDENTIAL IRRIGATION GEN SERVICE SCH d CH LG LG POWER Gins Oilfield Sec ............. Oilfield Pri ------------- ------------- Lighting ---- I -------------------- NONCOIN DEMAND ------------- 100.000000 ------------- ------------- 44.201793 7.869792 ------------- 5.957057 ••----------- ------------- 3.123791 ------------- 16.554526 3.816860 15,995984 1.387487 1.092710 2 RATCHET DEMAND 100.000000 38.714370 61.285630 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 3 COIN DEMAND 100.000000 44,688594 9,126957 6.202814 2.915273 15.882173 3.400630 15.227509 1.516855 1.039194 4 ENERGY FACTOR 100.000000 47.105200 11.353400 6.949400 1.954100 12.828200 4.004900 11.691600 1.916300 2.196900 5 CONSUMER 11 100.000000 64.547241 21.786545 6.551171 0.100048 0.456221 0.076037 3.589737 0.084041 2.808960 6 CONSUMER I2 WTD CONS 100.000000 42.223618 14.251682 21.427262 0.490851 7.460926 0.124549 4,696458, 0.137436 9.18741f 7 CONSUMER 13 1 PHASE 100.000000 84.476259 1.418533 4.886058 0.000000 0.000000 0.000000 0.000000 0.000000 9.219150 9 CONSUMER 14 3 PHASE 100.000000 0.696670 12.091403 9.836979 0.348335 3.971019 0.264735 12.498258 0.292601 0.000000 9 CONSUMER 15 CONS A/C 100.000000 50.073967 16.901400 12.705543 0.582111 10.617705 0.117975 5.569638 0.162991 3.268670 10 ACCT 366/367 100.000000 27.500000 37,500000 10.000000 4.000000 12.500000 5.000000 2.000000 1.500000 0.000000 11 ACCT 368 TRANSFRMRS 100.000000 55.592459 26.838003 10.150846 0.372844 1.700170 1.555341 3.790336 0.000000 0.000000 12 ACCI 369 SERVICES 1100.000000 52.100510 31.033087 6.843164 0.237518 1.083080 0.180513 8.522128 0.000000 0.000000 13 ACCI 370 METERS 100.000000 39.302450 19,389337 5.830034 0.796632 3.632642 0.605440 26.901715 3.542669 0.000000 14 ACCT 371 INST CONS P 100.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 100.000000 15 BASE REVENUE 100.000000 44.367247 12.895561 7.894158 2.256041 12.427068 3.433453 12.731847 1.651329 2.343296 16 PCRF REVENUE 100.000000 46.419542 10.258221 6.967472 2.124361 13.026414 4.877023 11.940794 2.159698 2.226474 11 OTHER REVENUE 100.000000 44.367247 12,895561 7.894158 2,256041 12.427068 3.433453 12.731847 1.651329 2.343296 101 TRANSMISSION PLANT 100.000000 44.201793 7.969792 5.957057 3.123791 16.554526 3.816860 15.995984 1.387487 1.092710 102 ACCT 364/365 100.000000 34.994070 27.919630 7.085358 1.842737 10.455017 2.199385 12.912286 0.863218 1.728298 103 TOTAL TRANSFORMERS 100.000000 53.405849 23,196769 9,345795 0.900930 4.551687 1.989474 6,133394 0.266349 0.209762 104 DISTRIBUTION PLANT 100.000000 37.241589 25.680197 7.674920 2.077254 9.393995 2.690754 9.596305 0.982956 4.662032 105 SUBTOTAL PLANT 100.000000 37.529227 24.944162 7.603927 2.120503 9.669912 2.737291 9.860778 0.999673 4.514526 106 GENERAL PLANT 100.000000 37.241589 25.680197 7.674920 2.077254 9.393995 2.690754 9.596305 0.982956 4.662032 107 PLANT 100.000000 37.507173 25.000597 7.609371 2.117187 9.667223 2.733723 9/840500 0.998391 4.525836 108 ENERGY REVENUE 100.000000 43.915346 13,476285 8.098208 2.285036 12.295096 3.115589 12.906031 1.539389 2.369019 109 OTHER REVENUE 100.000000 44.367247 12.895561 7.894158 2.256041 12.427068 3.433453 12.731847 1,651329 2.343296 110 REVENUES 100.000000 43.918160 13.472669 8.096937 2.204856 12.295918 3.117568 12.904947 1.540086 1.368859 III TRANSMISSION ETP 100.000000 44.201793 7.869792 5.957057 3.123791 16.554526 3.816860 15.995984 1.387487 1.092710 112 DIST OPERATIONS 100.000000 37.213106 23.253835 6.687243 1.540973 7.712489 1.769406 17.290058 1.918451 2.554439 113 DIST MAINTENANCE 100.000000 39.261057 24.466963 7.775494 2.138943 9.881128 2.784420 10.841626 1.125894 1.724474 114 SUBTOTAL EXPENSES 100.000000 38.361622 23.895059 /.277091 1.067864 8,901675 2.323526 13.763534 1.487036 2.101592 115 CONY ACCTS 100.000000 47.719618 15.932784 14.388436 0.700309 10.014272 0.396826 5.959954 0.281375 4.606426 116 COST SERV EXP 100.000000 50.073967 16.901400 12.705543 0.582111 10.617705 0.117975 5.569638 0.162991 3.268670 117 SUBTOTAL EXPENSES 100.000000 41.688962 21.191299 9.657419 1.460257 9.311104 1.647306 11,069426 1.066283 2.907944 lie ADMIN GENERAL 100.000000 41.450037 21,220284 9.459313 1.534527 9.428825 1.775361 11.034671 1.077847 3.011135 119 SUBTOTAL EXPENSES 100,000000 41.600247 21,202435 9.581312 1.488789 9.356329 1.696501 11.056074 1.070725 2.947587 120 Demand PP 100.000000 43.831507 16.609858 5.312933 2.497036 13.603651 2.912762 13.042907 1.299241 0.890107 121 TOTAL ENERGY 100.000000 47.105200 11.353400 6.949400 1.954100 12.828200 4.004900 11.691600 1.916300 2.196900 122 PURCHASED POWER 100.000000 45.793306 13.475921 6.298606 2.173334 13,141321 3.563902 12.237248 1.667136 1.669226 123 DEPRECIATION 100.000000 37.469508 25,096975 7.618667 2.111524 9.628475 2.727629 9.805869 0.996202 4.545151 124 TAXES 100.000000 39.700244 22.432006 8.417390 1.890651 9.798565 2.369834 10.602992 1.078063 3.710255 125 OTHER DEDUCTIONS 100.000000 42.082852 19.591842 9.272145 1.654775 9.968944 1.992324 11.441716 1.168423 2.826979 126 EXPENSES 100.000000 43.918158 16,524330 7.222089 2.003123 11,869053 3,028117 11.706561 1.454546 2.274024 127 NET PLANT 100.000000 37.479193 25.072195 7.616276 2.112980 9.638438 2.729196 9.614773 0.996765 4.5401B4 128 RATE BASE 100.000000 37.656762 24.057771 7.574441 2.114949 9.720085 2.734063 9.818668 1.006706 4.456554 119 IIIrUM itin _nnnnen 17.U9777 74.944167 7.603927 2.120503 9.669912 2.737791 9.960778 0.999673 4.514576 LA 0 o =r (/) lD a c r0 South plains Electric C000erative. Inc. lest rear Ended Sentember 30. 1992 Pr000sed Rates ALLOCATION FACTORS A,F, ---- FACTOR -------------------- TOTAL PERCENT ------------- RESIDENTIAL IRRIGATION GEN SERVICE SCH 1 CH LO LG POWER Gins Oilfield Sec Oilfield Pri Lighting 1 NUNCUIN DEMAND 10,009090 ----------•-- 44.101793 ------------- 7.869792 ------------- 5.957057 ----------------------•--- 3.123791 ------------- 16.554526 3.816860 ------------- 15.995984 ------------- ------------- 1.387487 1,092710 1 RATCHET DEMAND 100.00000 38.714370 61.285630 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 3 COIN DEMAND 100.000000 44.688594 9.126957 6.202014 2.915273 15.802173 3.400630 15.227509 1.516855 1.039194 4 ENERGY FACTOR 100.000000 47.105200 11.353400 6.949400 1.954100 12.028200 4.004900 11.691600 1.916300 2.196900 5 CONSUMER 11 100.000000 64.547241 21.786545 6.551171 0.100048 0.456721 0.0/6037 3,589737 0.084041 2.800960 e CONSUMER 12 WID CONS 100.000000 42.223618 14.251682 21,427262 0.490051 /.460928 0.124349 4.696458 0.137436 9.187413 7 CONSUMER 13 1 PHASE 100.000000 84.416259 1.418533 4.086058 0.000000 0.000000 0.000000 0/000000 0.000000 9.211150 6 CONSUMER 14 3 PHASE 100.000000 0.696670 72.091403 9.836979 0.348335 3.971019 0.264735 12.498258 0.292601 0/000000 CONSUMER 15 CONS ArC 100.000000 50.013967 16.901400 12.705543 0.582111 IV.617705 0,117975 5.569638 0.162991 3.268670 10 ACCT 3667367 100.000000 27.500000 57.500000 10.000000 4.000000 12.500000 5/000000 2.000000 1.500000 0.000000 II ACCT 368 TRANSFAMRS 100.000000 55.592459 26.838003 10.150846 0.572844 1.700170 1.555341 3.790336 0.000000 0.000000 17 ACCT 369 SERVICES 100.000000 52.100510 31.033087 6.843164 0.237518 1.083080 0.180513 8.522128 0.000000 0.000000 13 ACCI 3?0 METERS 100.000000 39.301450 19.388337 5.830034 0.196632 3.632642 0.605440 26.901795 3.542669 0.000000 14 ACCT 371 INST CONS P 100.000000 0/000000 0.000000 0/000000 0.000000 0.000000 0.000000 0.000000 0.000000 100.000000 15 BASE REVENUE 100.000000 44.801125 13.077869 1.611365 2.175223 12.600937 3.424757 12.275752 1.625050 2.401082 16 FCRF REVENUE 100.000000 46.419542 10.258221 6.967472 2.124361 13.026414 4.877023 11.940794 2.159698 2.226474 17 OTHER REVENUE 100.000000 44.361247 12.895561 7,894158 2.256041 12.427060 3.433453 12.731847 1.651321 2,343296 to TRANSMISSION PLANT 100.000000 44.201793 7.869792 5.957057 3.123791 16.554526 3.816860 15.995984 1.387487 1.092710 102 ACCT 3641365 100.000000 34,994070 27.919630 7.005358 1.842737 10.455017 2.199385 12.912286 0.863218 1.728298 103 TOTAL TRANSFORMERS 100.000000 53.405849 23,196769 9.345785 0,900930 4.551687 1.969474 6.133394 0.266349 0.109762 104 DISTRIBUTION PLANT 100.000000 37.241589 15,680197 7.674920 2.077254 9.393995 2.690754 9.596305 0.982956 4.662032 105 SUBTOTAL PLANT 100,000000 37.529227 24.944162 7.603927 2.120503 9.689912 2,737291 9.660778 0,999673 4.514526 l06 GENERAL PLANT 100.000000 37.241589 25.680197 7.674920 2.077254 9.393995 2.690754 9.596305 0.982956 4.662032 I0? PLAN1 100.000000 31.507173 25.000597 7.609371 2.117187 9.667223 2,733723 9.840500 0.998391 4.525036 108 ENERGY REVENUE 100.000000 44.467480 15.671810 1.746Y96 2.105937 12.511313 3.118095 12.346309 1.513398 2.437861 109 OTHER REVENUE 100.000006 44.367247 12.895561 7.894158 2.256041 12.427068 3.433453 12.731047 1.651329 1.s43196 110 REVENUES 100.000000 44.466883 13.667185 1.747873 2.186354 12.510811 3.120769 12.348606 1.514220 2.437298 III TRANSMISSION EXP 100.000000 44.201793 7.869792 5,957057 3.123791 16.554526 3.016860 15.995984 1.367487 1.092710 112 DIST OPERATIONS 100.000000 37.273106 23.253835 6.687243 1.540973 7.712489 1.769406 17.290059 1.918451 2.554439 113 DIST MAINTENANCE 100.000000 39.261057 24.466963 7.775494 2.138943 9.881128 2.784420 10.841626 1.125894 1.724474 114 SUBTOTAL EXPENSES 100.000000 38,361872 23.895059 1.277891 1.867864 8.901675 2,323526 13,783534 1.487036 2.101592 115 CONS ACCIS 100.000000 47.756412 15.948033 14.364761 0.693549 10.018B16 0.396102 5.921804 0.277244 4.611260 cn n 116 LUST SERV EXP 100.000000 50.073967 16.901400 12.705543 0.582111 10.617705 0.117975 5.569638 0.162991 3,268670 S p cn lit SUBTOTAL EXPENSES 1001000000 41.700073 21.195904 9,650276 1.458215 1.315496 1.647087 11.057905 1.065639 2.909404 a tie ADMiN GENERAL 100.000000 41.499163 21.231551 9.440092 1.529079 9.440659 1,775287 11.003901 1.076321 3.014950 119 SUBTOTAL EXPENSES 100.000000 41.618663 21.209599 9.569525 1.485439 9.363580 1.696338 11.037158 1.069743 2.949955 120 De4and PP 100.000000 43.831507 16.609058 5.312933 2.497036 13.603651 2.912762 13.042907 1,299241 0.890107 n 121 TOTAL ENERGY 100.000000 47.105200 11.353400 6,949400 1.954100 12.828200 4.004900 11,691600 1.916300 2.196900 122 PURCHASED POWER 100.000000 45.783306 13.475921 6.188606 2.173334 13.141321 3.563902 11.23724e 1.66/136 1.661226 T1 113 123 DEPRECIATION 100/000000 37.469508 25,096975 7.618667 2.111524 9.628475 2.727629 9.805869 0.996202 4.545151 CD 124 TAXES 100.000000 19.760166 22.453474 8,379245 1.879879 9.822046 2.570087 10.542151 1.07519E 3.717754 125 OTHER DEDUCTIONS 100.000000 42.212527 19.638272 9,189601 1.631464 10.019756 1,992884 11,310064 1.162227 2.043204 126 EXPENSES 100/000000 43.924525 16.526739 7.218021 2.001969 11.871555 3.028069 11.700047 1.454219 2.274835 127 NET PLANT 100.000000 37.479193 25.072195 7.616276 2.112960 Y.638438 2.729196 9.814773 0.996765 4.540184 128 RATE BASE 1001000000 37.654434 24,656950 7.575921 2.115367 9.719174 2.734048 9.661027 1.006815 4.456264 179 leTLQGCT 166.000060 37.529227 24.944162 1.603927 2.120503 9.689912 2,731291 9.860778 0.999673 4,514526 1 I r Cos. Schedule C-3.0 Page 1 �of 17 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 1: NONCOIN DEMAND Comp: Demand: 100.000000 Customer: 0.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 Class Name Number Percent ------------- ------------------ Res 426,157.00 ---------- 44.201793 Irrig 75,874.00 7.869792 Gen Svc 54,834.00 5.687484 Sch & Ch Sm 2,599.00 0.269573 Sch & Ch Lg 30,117.00 3.123791 Lg Pwr 159,605.00 16.554526 Gins 36,799.00 3.816860 Oilfield Sec 154',220.00 15.995984 Oilfield Pri 13,377.00 1.387487 Lighting ------------------------------- 10,535.00 1.092710 ---------- TOTAL 964,117.00 100.000000 Group Name ------------- ------------------ Number Percent ---------- RESIDENTIAL 426,157.00 44.201793 IRRIGATION 75,874.00 7.869792 GEN SERVICE 57,433.00 5.957057 SCH & CH LG 30,117.00 3.123791 LG POWER 159,605.00 16.554526 5.ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. r Test Year Ended September 30, 1992 } Present Rates Allocation Factor # 2: RATCHET DEMAND COS Schedule C-3.0 Page 2 of 17 Comp: Demand: 100.000000 Customer: 0.000000 l _ Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 Class Name Number ------------ Weight -------------- Product Percent ---------- Res 50,036.00 1.000000 50,036.00 38.714370 Irrig 79,208.00 1.000000 79,208.00 61.285630 Gen Svc 0.00 0.000000 0.00 0.000000 _ Sch & Ch Sm 0.00 0.000000 0.00 0.000000 Sch & Ch Lg 0.00 0.000000 0.00 0.000000 Lg Pwr 0.00 0.000000 0.00 0.000000 Gins 0.00 0.000000 0.00 0.000000 Oilfield Sec 0.00 0.000000 0.00 0.000000 Oilfield Pri Lighting 0.00 0.00 ------------ 0.000000 0.000000 -------------- 0.00 0.00 0.000000 0.000000 ------------- TOTAL ------------ 129,244.00 1.000000 129,244.00 ---------- 100.000000 :. Group Name ------------- Number ------------------------ Weight -------------- Product Percent ---------- RESIDENTIAL 50,036.00 1.000000 50,036.00 38.714370 IRRIGATION 79,208.00 1.000000 79,208.00 61.285630 GEN SERVICE 0.00 0.000000 0.00 0.000000 SCH & CH LG 0.00 0.000000 0.00 0.000000 r LG POWER 0.00 0.000000 0.00 0.000000 r F,'.ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 3: COIN DEMAND r., Comp: Demand: 100.000000 Customer: 0.000000 Energy: 0.000000 Fuel: 0.000000 r' Revenue: 0.000000 Class Name - Number --- Percent Res 342,606.00 44.688594 Irrig 69,972.00 9.126957 Gen Svc 45,688.00 5.959418 l l Sch & Ch Sm 1,866.00 0.243396 Sch & Ch Lg 22,350.00 2.915273 Lg Pwr 121,761.00 15.882173 Gins 26,071.00 3.400630 Oilfield Sec 116,742.00 15.227509 Oilfield Pri Lighting 11,629.00 7,967.00 1.516855 1.039194 ------------- ------------------ ---------- TOTAL 766,652.00 100.000000 r 1 Group Name Number Percent ------------- RESIDENTIAL ------------------ ---------- 342,606.00 44.688594 IRRIGATION 69,972.00 9.126957 GEN SERVICE 47,554.00 6.202814 SCH & CH LG 22,350.00 2.915273 r LG POWER 121,761.00 15.882173 COS Schedule C-3.0 Page 3 of 17 Fase: SPECPRES Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 l Present Rates Allocation Factor # 4: ENERGY FACTOR r Comp: Demand: 0.000000 Customer: 0.000000 Energy: 100.000000 Fuel: 0.000000 Revenue: 0.000000 Class -Name --- ---Percent Res 47.105200 Irrig 11.353400 Gen Svc 6.726900 I I Sch & Ch Sm 0.222500 Sch & Ch Lg 1.954100 Lg Pwr 12.828200 Gins 4.004900 Oilfield Sec 11.691600 Oilfield Pri Lighting----- 1.916300 --2_196900 TOTAL 100.000000 Group Name Percent RESIDENTIAL 47.105200 IRRIGATION 11.353400 `, GEN SERVICE 6.949400 SCH & CH LG 1.'954100 LG POWER 12.828200 7 r r C 4 COS Schedule C-3.0 Page 4 of 17 Fl.ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 COS Schedule C-3.0 Page 5 of 17 South Plains Electric Cooperative, Inc. r' y Test Year Ended September 30, 1992 Present Rates r k; Allocation Factor # 5: CONSUMER #1 Comp: Demand: 0.000000 Customer: 100.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 ` Class Name ------------- Number ---------�-------------- Weight -------------- Product Percent Res 16,129 00 1.000000 16,129.00 64.547241 Irrig 5,444.00 1.000000 5,444.00 21.786545 Gen Svc 1,596.00 1.000000 1,596.00 6.387091 !_ Sch & Ch Sm 41.00 1.000000 41.00 0.164079 Sch & Ch Lg 25.00 1.000000 25.00 0.100048 r Lg Pwr 114.00 1.000000 114.00 0.456221 Gins 19.00 1.000000 19.00 0.076037 Oilfield Sec 897.00 1.000000 897.00 3.589737 Oilfield Pri Lighting ----- 21.00 ----7,019.00 --- ------------ 1.000000 0.100000 -------------- 21.00 701.90 0.084041 2.808960 -------- TOTAL 31,305.00 0.798208 24,987.90 ---------- 100.000000 Group Name Number Weight Product ------------------------ Percent ------------- RESIDENTIAL 16,129.00 -------------- 1.000000 16,129.00 ---------- 64.547241 IRRIGATION 5,444.00 1.000000 5,444.00 21.786545 GEN SERVICE 1,637.00 1.000000 1,637.00 6.551171 SCH & CH LG 25.00 1.000000 25.00 0.100048- LG POWER 114.00 1.000000 114.00 0.456221 F r 5ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 i South Plains Electric Cooperative, Inc Test Year Ended September 30, 1992 Present Rates �- Allocation Factor # 6: CONSUMER #2 WTD CONS COS Schedule C-3.0 Page 6 of 17 r Comp: Demand: 50.000000 Customer: 50.000000 Energy: 0.000000 Fuel: 0.000000 i" Revenue: 0.000000 E Class Name __`___Number ______Weight Product Percent r _____________ _ ___ ______________ __________ Res 10,129.00 1.000000 16,129.00 42.223618 Irrig 5,444.00 1.000000 5,444.00 14.251682 Gen Svc 1,596.00 5.000000 7,980.00 20.890599 Sch & Ch Sm 41.00 5.000000 205.00 0.536663 Sch & Ch Lg 25.00 7.500000 187.50 0.490851 Lg Pwr 114.00 25.000000 2,650.00 7.460928 Gins 19.00 2.500000 47.50 0.124349 Oilfield Sec 897.00 2.000000 1,794.00 4.696458 Oilfield Pri 21.00 2.500000 52.50 0.137438 Lighting ------------- 7,019.00 ------------------------ 0.500000 -------------- 3,509.50 9.187413 ---------- TOTAL 31,305.00 1.220220 38,199.00 100.000000 Group Name ------------- Number ------------ Weight -------------------------- Product Percent ---------- RESIDENTIAL 16,129.00 1.000000 16,129.00 42.223618 IRRIGATION 5,444.00 1.000000 5,444.00 14.251682 GEN SERVICE 1,637.00 5.000000 8,185.00 21.427262 SCH & CH LG 25.00 7.500000 187.50 0.490851 LG POWER 114.00 25.000000 2,850.00 7.460928 5.ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 COS 7 Schedule C-3.0 Page 7 of 17 South Plains Electric Cooperative, Inc. �- Test Year Ended September 30, 1992 Present Rates r- Allocation Factor # 7: CONSUMER #3 1 PHASE i Comp: Demand: 60.000000 l Customer: 40.000000 l Energy: 0.000000 Fuel: 0.000000 r' Revenue: 0.000000 Class Name Number ------------ Weight -------------- Product Percent ------------- Res ------------ 16,079.00 1.000000 16,079.00 ---------- 84.476259 Irrig 270.00 1.000000 270.00 1.418533 Gen Svc 925.00 1.000000 925.00 4.859789 Sch & Ch Sm 5.00 1.000000 5.00 0.026269 Sch & Ch Lg 0.00 0.000000 0.00 0.000000 Lg Pwr 0.00 0.000000 0.00 0.000000 Gins 0.00 0.000000 0.00 0.000000 Oilfield Sec 0.00 0.000000 0.00 0.000000 Oilfield Pri 0.00 0.000000 0.00 0.000000 Lighting ------------- 71019.00 ------------------------ 0.250000 ----------- 1,754.75 --- 9.219150 ---------- TOTAL 24,298.00 0.783346 19,033.75 100.000000 Group Name ------------- Number ------------------------ Weight -------------- Product Percent ---------- RESIDENTIAL 16,079.00 1.000000 16,079.00 84.476259 IRRIGATION 270.00 1.000000 270.00 1.418533 GEN SERVICE 930.00 1.000000 930.00 4.886058 SCH & CH LG 0.00 0.000000 0.00 0.000000 LG POWER 0.00 0.000000 0.00 0.000000 h F.-ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 r COS Schedule C-3.0 Page 8 of 17 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates r l Allocation Factor # 8: CONSUMER #4 3 PHASE Comp: Demand: 60.000000 Customer: 40.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 ClassNamePercent --- ------Number ---_-- -------Product -------------- ---------- Res 50.00 1.000000 50.00 0.696670 Irrig 5,174.00 1.000000 5,174.00 72.091403 Gen Svc 670.00 1.000000 670.00 9.335377 i Sch & Ch Sm 36.00 1.000000 36.00 0.501602 Sch & Ch Lg 25.00 1.000000 25.00 0.348335 Lg Pwr 114.00 2.500000 285.00 3.971019 Gins 19.00 1.000000 19.00 0.264735 Oilfield Sec 897.00 1.000000 897.00 12.498258 Oilfield Pri 21.00 1.000000 21.00 0.292601 Lighting ------------- 0.00 ------------------------ 0.000000 -------------- 0.00 0.000000 ---------- TOTAL 7,006.00 1.024408 7,177.00 100.000000 Group Name ------------- Number ------------------------ Weight -------------- Product Percent RESIDENTIAL 50.00 1.000000 50.00 ---------- 0.696670 IRRIGATION 5,174.00 1.000000 5,174.00 72.091403 GEN SERVICE 706.00 1.000000 706.00 9.836979 r SCH & CH LG LG POWER 25.00 114.00 1.000000 2.500000 25.00 285.00 0.348335, 3.971019 F [I- F,::ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 9: CONSUMER #5 CONS A/C COS Schedule C-3.0 Page 9 of 17 Comp: Demand: 0.000000 Customer: 100.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 Class Name Number ------------------------ Weight -------------- Product Percent ------------- Res 16,129.00 1.000000 16,129.00 ---------- 50.073967 Irrig 51444.00 1.000000 5,444.00 16.901400 Gen Svc 1,596.00 2.500000 3,990.00 12.387323 Sch & Ch Sm 41.00 2.500000 102.50 0.318221 Sch & Ch Lg 25.00 7.500000 187.50 0.582111 Lg Pwr 114.00 30.000000 3,420.00 10.617705 Gins 19.00 2.000000 38.00 0.117975 Oilfield Sec 897.00 2.000000 1,794.00 5.569638 Oilfield Pri 21.00 2.500000 52.50 0.162991 Lighting 7,019.00 ------------------------ 0.150000 1,052.85 3.268670 ------------- TOTAL 31,305.00 -------------- 1.028920 32,210.35 ---------- 100.000000 Group Name Number ------------------------ Weight -------------- Product Percent ------------- RESIDENTIAL 16,129.00 1.000000 16,129.00 ---------- 50.073967 IRRIGATION 5,444.00 1.000000 5,444.00 16.901400 GEN SERVICE 1,637.00 2.500000 4,092.50 12.705543 SCH & CH LG 25.00 7.500000 187.50 0.582111- LG POWER 114.00 30.000000 3,420.00 10.617705 rase: SPECPRES Solved: 03-09-1993 @ 20:22:52 k South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 P Present Rates Allocation Factor # 10: ACCT 366/367 Comp: Demand: 50.000000 Customer: 50.000000 Energy: 0.000000 Fuel: 0.000000 a, Revenue: 0.000000 r 4` Class -Name--- ---Percent Res 27.500000 Irrig 37.500000 Gen Svc 10.000000 Sch & Ch Sm 0.000000 Sch & Ch Lg 4.000000 Lg Pwr 12.500000 Gins 5.000000 Oilfield Sec 2.000000 Oilfield Pri Lighting 1.500000 -------- ----- TOTAL --0_000000 ----- 100.000000 Group Name Percent RESIDENTIAL 27.500000 IRRIGATION 37.500000 GEN SERVICE 10.000000 SCH & CH LG 4.000000 LG POWER 12.500000 I f r COS Schedule C-3.0 Page 10 of 17 1'.ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 F South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 11: ACCT 368 TRANSFRMRS Class Name Res Irrig Gen Svc Sch & Ch Sm Sch & Ch Lg Lg Pwr Gins Oilfield Sec Oilfield Pri Lighting ------------- TOTAL Group Name ------------- RESIDENTIAL IRRIGATION GEN SERVICE SCH & CH LG LG POWER N COS Schedule C-3.0 Page 11 ofi 17 Comp: Demand: 60.000000 Customer: 40.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 Number ------------ Weight Product Percent ------------ 161,290.00 -------------- 26.000000 4,193,540.00 ---------- 55.592459 95,270.00 21.250000 2,024,487.50 26.838003 47,880.00 15.500000 742,140.00 9.838320 - 2,050.00 11.500000 23,575.00 0.312526 3,125.00 9.000000 28,125.00 0.372844 14,250.00 9.000000 128,250.00 1.700170 18,050.00 6.500000 117,325.00 1.555341 13,455.00 21.250000 285,918.75 3.790336 0.00 0.000000 0.00 0.000000 0.00 0.000000 0.00 0.000000 355,370.00 21.226781 7,543,361.25 100.000000 Number Weight Product Percent 161,290.00 26.000000 4,193,540.00 55.592459 95,270.00 21.250000 2,024,487.50 26.838003 49,930.00 15.335770 765,715.00 10.150846 3,125.00 9.000000 28,125.00 0.372844- 14,250.00 9.000000 128,250.00 1.700170 ease: SPECPRES Solved: 03-09-1993 @ 20:22:52 COS Schedule C-3.0 Page 12 of 17. South Plains Electric Cooperative, Inc. k Test Year Ended September 30, 1992 Present Rates Allocation Factor # 12: ACCT 369 SERVICES Comp: Demand: 0.000000 i Customer: 100.000000 I Energy: 0.000000 Fuel: 0.000000 r' Revenue: 0.000000 Class Name Number ------------ Weight Product Percent ------------- Res 16,129.00 ------------ 85.000000 -------------- 1,370,965.00 ---------- 52.100510 Irrig 5,444.00 150.000000 816,600.00 31.033087 Gen Svc 1,596.00 110.000000 175,560.00 6.671772 Sch & Ch Sm 41.00 110.000000 4,510.00 0.171393 Sch & Ch Lg 25.00 250.000000 6,250.00 0.237518 Lg Pwr 114.00 250.000000 28,500.00 1.083080 Gins 19.00 250.000000 4,750.00 0.180513 Oilfield Sec 897.00 250.000000 224,250.00 8.522128 Oilfield Pri 21.00 0.000000. 0.00 0.000000 Lighting 7,019.00 ------------ 0.000000 ------------ 0.00 -------------- 0.000000 ------------- TOTAL 31,305.00 84.056381 21631,385.00 ---------- 100.000000 Group Name Number ------------ Weight ------------ Product -------------- Percent ------------- RESIDENTIAL 16,129.00 85.000000 1,370,965.00 ---------- 52.100510 IRRIGATION 5,444.00 150.000000 816,600.00 .31.033087 GEN SERVICE 1,637.00 110.000000 180,070.00 6.843164 SCH & CH LG 25.00 250.000000 6,250.00 0.237518 LG POWER 114.00 250.000000 28,500.00 1.083080 7 r i Flase: SPECPRES Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 13: ACCT 370 METERS Comp: Demand: 0.000000 Customer: 100.000000 Energy: 0.000000 Fuel: 0.000000 f Revenue: 0.000000 Class Name Number Weight ------------- Res ------------ 16,129.00 ------------ 65.000000 Irrig 5,444.00 95.000000 Gen Svc 1,596.00 95.000000 Sch & Ch Sm 41.00 95.000000 Sch & Ch Lg 25.00 850.000000 Lg Pwr 114.00 850.000000 Gins 19.00 850.000000 Oilfield Sec 897.00 800.000000 Oilfield Pri 21.00 4500.000000 Lighting ------------- 7,019.00 ------------ 0.000000 ------------ TOTAL 31,305.00 85.209391 Group Name ------------- Number ------------ Weight ------------ RESIDENTIAL 16,129.00 65.000000 IRRIGATION 5,444.00 95.000000 GEN SERVICE 1,637.00 95.000000 SCH & CH LG 25.00 850.000000 LG POWER 114.00 850.000000 r COS Schedule C-3.0 Page 13 of 17 Product -------------- Percent 1,048,385.00 ---------- 39.302450 517,180.00 19.388337 151,620.00 5.684016 3,895.00 0.146018 21,250.00 0.796632 96,900.00 3.632642 16,150.00 0.605440 717,600.00 26.901795 94,500.00 3.542669 0.00 -------------- 0.000000 2,667,480.00 ---------- 100.000000 Product -------------- Percent 1,048,385.00 ---------- 39.302450 517,180.00 19.388337 155,515.00 5.830034 21,250.00 0.796632 96,900.00 3.632642 gases SPECPRES .Solved: 03-09-1993 @ 20:22:52 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates �- l: Allocation Factor # 14: ACCT 371 INST CONS P Comp: Demand: 0.000000 Customer: 100.000000 Energy: 0.000000 Fuel: 0.000000 Revenue: 0.000000 Class Name ------------- Percent ---------- Res 0.000000 Irrig 0.000000 Gen Svc 0.000000 Sch & Ch Sm 0.000000 Sch & Ch Lg 0.000000 Lg Pwr 0.000000 Gins 0.000000 ` Oilfield Sec 0.000000 Oilfield Pri 0.000000 �. Lighting 100.000000 TOTAL 100.000000 Group Name Percent ------------- RESIDENTIAL ---------- 0.000000 IRRIGATION 0.000000 GEN SERVICE 0.000000 SCH & CH LG 0.000000 LG POWER 0.000000 COS Schedule C-3.0 Page 14 of 17 ease: SPECPRES -Solved: 03-09-1993 @ 20:22:52 l! South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates PM Allocation Factor # 15: BASE REVENUE Comp: Demand: 0.000000 Customer: 0.000000 l l Energy: 100.000000 Fuel: 0.000000 s Revenue: 0.000000 Class Name ------------- -Number -------�------------- Percent Res 11 034'499.00 44.367247 Irrig 3,207,232.00 12.895561 Gen Svc 1,902,930.00 7.651255 Sch & Ch Sm 60,412.00 0.242903 Sch & Ch Lg 561,096.00 2.256041 Lg Pwr 3,090,714.00 12.427068 Gins 853,928.00 3.433453 Oilfield Sec 3,166,515.00 12.731847 Oilfield Pri Lighting----- 410,699.00 -_---_--582,797_00--2_343296 1.651329 TOTAL 24,870,822.00 100.000000 Group Name Number ------------- ------------------ Percent RESIDENTIAL ---------- 11,034,499.00 44.367247 IRRIGATION 3,207,232.00 12.895561 GEN SERVICE 1,963,342.00 7.894158 SCH & CH LG 561,096.00 2.256041 LG POWER 3,090,714.00 12.427068 t, {FM 1 COS Schedule C-3.0 Page 15 of 17 F-ase: SPECPRES Solved: 03-09-1993 @ 20:22:52 r r South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates Allocation Factor # 16: PCRF REVENUE k Comp: Demand: 0.000000 r Customer: 0.000000 4 Energy: 100.000000 Fuel: 0.000000 Revenue: 0.000000 Class Name ------------- Number -------------�------------ Percent Res -2 083 368 00 46.419542 Irrig -460,402.00 10.258221 Gen Svc -302,429.00 6.738423 Sch & Ch Sm -10,280.00 0.229049 Sch & Ch Lg -95,344.00 2.124361 Lg Pwr -584,642.00 13.026414 Gins -218,887.00 4.877023 Oilfield Sec -535,918.00 11.940794 Oilfield Pri -96,930.00 2.159698 r. Lighting --------_99,927_00 2.226474 TOTAL -4,488,127.00 100.000000 Group Name Number Percent ------------- RESIDENTIAL ------------------ ---------- -2,083,368.00 46.419542 IRRIGATION -460,402.00 10.258221 GEN SERVICE -312,709.00 6.967472 SCH & CH LG -95,344.00 2.124361 LG POWER -584,642.00 13.026414 r c r COS Schedule C-3.0 Page 16 of 17 rase: SPECPRES Solved: 03-09-1993 @ 20:22:52 F South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates r- Allocation Factor # 17: OTHER REVENUE L Comp: Demand: Customer: f Energy: Fuel: Revenue: Cl Re I G 0.000000 0.000000 0.000000 0.000000 100.000000 ass Name Percent e Sc Sc L g i Gi Oi Oi Li (� T F G I G L G u i 1 F I 1 0.000000 0.000000 0.000000 0.000000 100.000000 ass Name Percent s 44.367247 rrig 12.895561 n Svc 7.651255 h & Ch Sm 0.242903 h & Ch Lg 2.256041 Pwr 12.427068 ns 3.433453 Meld Sec 12.731847 Meld Pri 1.651329 ghting 2.343296 --------------------- TO 100.000000 roup Name Percent ESIDENTIAL 44.367247 RRIGATION 12.895561 E C N SERVICE 7.894158 H & CH LG 2.256041 POWER 12.427068 COS Schedule C-3.0 Page 17 of 17 COS Schedule C-3.0 Page 17 of 17 COS Schedule C-4.0 1 RESIDENTIAL IRRIGATION GENERAL SERVICE SCH $ CH SMALL SCH $ CH LARGE LARGE POWER GINS r OILFIELD SECDRY �OILFIELD PRIMATY SECURITY LIGHTS TOTALS r I C r t r FlqG= r SOUTH PLAINS ELECTRIC COOPERATIVE, INC. ENERGY ALLOCATION FACTOR Kwh % Kwh Kwh % Of Sold Losses Losses Purchased Total 149,371,203 9.88% 14,761,412 164,132,615 47.1050 36,001,843 9.88% 3,557,835 39.559,678 11.3534 21,331,312 9.88% 2,108,039 23,439,351 6.7269 705,694 9.88% 69,739 775,433 0.2225 6,196,620 9.88% 612,373 6,808,993 1.9541 40,678,646 9.88% 4,020,013 44,698.659 12.8282 12,699,580 9.88% 1.255,019 13,954.599 4.0049 37,074,314 9.88% 3,663,820 40,738,134 11.6916 6,677,091 6,677,091 1.9163 6,966,553 9.88% 688,460 7.655,013 2.1969 317,702,856 30,736,710 348,439,566 100.0000 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: JANUARY.1992 1#OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,ee 14,021 10,405,268 35.4191% 125,583,210 28,993 14,330 14.057 5,943 20,279 34.4% RES SPACE HT 3d4 577 1,159,420 3.9240% 13,913,040 2AN 1,588 1,318 534 2,122 3.0% RES WTR HT 33 1,170 1,051,229 5.5885% 19,814,748 4,280 2,202 2018 816 3,080 5.2% RES WTR HT SPHT34 414 1,211,781 4.1011% 14,541,132 2A23 1,800 1,2e3 512 2.172 3.7% TOTAL RES 18,166 14,487.878 49.0327% 173,852.138 39,101 19,846 19,254 7,807 27,053 47.0% IRRIGATION 5.20,21,22,23 5,492 123,412 0.4177% 1,480,944 200 109 91 37 20e 0.3% GEN SVC 0.7 1.393 2.027,993 e.8e3e% 24,335,910 5,307 2,778 2029 1,025 3,804 6.5% SCH d CH SMALL 5e 39 59,037 0.1998% 708.444 181 81 101 41 122 0.2% TOTAL GEN SVC SCH d CHRCH 1,e32 2,087,030 7.0634% 25A44,3eO 5,489 2,859 2,830 1,Oee 3,925 e.7% LARGE POWER 8,77 112 3.735,117 12.6413% 44,821,404 13.470 5,117 8,333 3,387 8,503 14.4% SCH & CH LG 58 2e 547,920 1.8544% 8,575,040 2,084 751 1,333 541 1.291 2.2% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LGPWR 138 4,283,037 14.4957% 51,39e,444 15,554 5,8e7 9,887 3,927 9,795 1e.e% GINS 9 20 3,888,800 13.1014% 40A05,600 10,e54 5,327 5,327 2,100 7,487 12.7% OILFIELD SECDRY 10 913 3.505.372 11.8678% 42,078,864 12.280 4,804 7.476 3,031 7,835 13.3% OILFIELD PRI 11.12 21 589,310 1.0945% 7,071,720 703 807 (44) (18) 789 1.3% OTHER PRIMARY e8 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 21 509,310 1.9945% 7.071,720 7e3 807 (44) (18) 789 1.3% PUB d OS UTTES 18.19 27 38.151 0.1291% 457,812 11e 52 e4 2e 78 0.1% SECRTYLITES 6,923 542.972 1.8377% 6,515.004 1,053 744 909 309 1.112 1.9% TOTALS 31,354 29,540,962 100.0000% 354,8e3,544 85,870 40,475 45.394 18.405 58,880 100.0% 85,870 40,475 45,394 18,405 58,880 PERIOD: FEBRUARY, 1992 +#OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %Of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,ee 13,882 8,174,340 37.2797% 98.092,080 23,272 11,198 12,075 e,8e9 18,087 34.4% RES SPACE HT 3d4 5e0 1,081,895 4,8429% 12,742.740 2A" 1,455 1,224 697 2,151 4.1% RES WTTt HT 33 970 1.313.297 5.9894% 15.759,504 3,427 1,799 1,028 928 2.725 5.2% RES WTTt HT SPHT34 337 1.037,238 4.7304% 12,440,850 2.498 1.421 1.077 013 2A34 3.9% TOTALRES 15,755 11,580,770 52.8423% 139,041,240 31,870 15,872 10,004 9,105 24977 47.5% IRRIGATION 5,20,21,22,23 8,531 50,120 0.2288% 801,812 105 89 37 21 90 0.2% GEN SVC 8,7 1,555 1,591,427 7.2578% 19.097,124 3.351 2,180 1,171 800 2,840 5.4% SCH d CH SMALL 5e 39 54,172 0.2471% 850,064 lea 74 94 53 128 0.2% TOTAL GEN SVC SCH d CHRCH 1,594 1,645,599 7.5049% 19,747,188 3.519 2,254 1,205 720 2074 5.7% LARGE POWER 8,77 110 2039,240 13.4046% 35,270,880 12,078 4,024 8,952 8,092 9,119 17.4% SCH d CH LG 58 2e 407,220 2.1308% 5,808,e40 2,118 e40 1,470 840 1,480 22% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LG PWR 130 3,406,400 15.5354% 40,877.520 15,094 4,8e8 10.428 5,932 10,599 20.2% GINS 9 20 1,354,940 8.1701% 1e,250,880 3,710 1,855 1,855 1,035 2.910 5.5% OILFIELD SECDRY 10 904 2,871,284 13.0947% 34.455,408 12,791 3,933 8,858 5,039 8,972 17.1% OILFIELD PRI 11.12 21 435,081 1.9842% 5,220,072 747 5" 151 ee 052 1.3% OTHER PRIMARY e8 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 21 435,081 1.9842% 5,220,972 747 59e 151 Be 682 1.3% PUB d OSLTTES 18,16,19 27 31,947 0.1457% 383,304 97 44 53 30 74 0.1% SECRTYLITES e,92e 645,558 2.4880% e,54e,872 1,ee1 747 913 520 1.207 2A% TOTALS 30,917 21.027,083 100.0000% 203,124.750 89,802 30,037 39,585 22,508 52,645 100.0% 89,002 30,037 39,505 22,508 62,545 -O N m iv 0 O un =- N (D (D r� c O (D -h c-1 `�I 1 Ln 0 Pepe 1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: MARCH.1992 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTD4L 1,2,06 14,482 7,407,a66 37.8773% 89.a11,992 21,587 10,230 11,357 6,492 10.722 34.1% RES SPACE HT 3d4 581 721,155 3.8578% 8,853,860 1,909 988 921 527 1,515 3.1% RES WTR HT 33 1.184 1,223,437 8.2055% 14,881,244 3,285 1,678 1,a09 920 2.598 5.3% RES WTR HTSPHT34 428 704.694 4.0308% 9,530,328 2A1a 11089 930 532 1.820 3.3% TOTALRES 1a,a75 10,200,952 51.7714% 122.483.424 28.800 13,982 14,818 8.470 22A52 45.8% IRRIGATION 5.20.21,22,23 5,385 118,565 0.6014% 1.422,780 250 162 88 50 212 0.4% GEN SVC a,7 1.592 1,564.659 7.9362% 18,775,908 3,314 2.143 1.171 a69 2.813 5.7% SCH d CH SMALL 56 40 55,881 0.2834% 070,572 173 77 96 55 131 0.3% TOTAL GEN SVC SCH d CHRCH 1,632 1,820,540 8.2197% 19,448,480 3,487 2,220 1,207 724 2,944 6.0% LARGE POWER 8,77 105 2571,989 13.0456% 30,863,868 10,930 3,523 7,407 4.234 7,757 15.8% SCH d CH LG a8 22 376,980 1.9121% 4.523.780 1,951 a16 1,435 820 1,338 2.7% OTHER LP 78 2 87,947 0.4456% 1,054,104 309 120 249 142 282 0.5% TOTAL LGPWR 129 3,030,816 15.4032% 36,441.792 13.250 4.160 9,090 5.106 0,350 19.1% GINS 9 20 254,400 1.2904% 3,052,800 1,742 348 1.394 797 1.145 2.3% OILFIELD SECDRY 10 807 2.078,840 15.1002% 35,746.188 12,932 4,081 8.351 5.000 9.140 18.6% OILFIELD PRI 11.12 18 450,979 2.2874% 5,411,748 788 a18 170 07 715 1.5% OTHER PRIMARY 08 a 470,596 2.3859% 5,847,152 2.518 045 1.873 1,071 1,710 3.5% TOTAL PRIMARY 23 921,575 4.8744% 11.05a,900 3,300 1.202 2,A44 Lies 2,431 5.0% PUB d OS UTES 18.19 27 30.732 0.1550% 368.784 94 42 51 20 72 0.1% SECRTYLITES 6,066 546,996 2.7745% a,563,952 11065 749 918 524 1,273 2.6% TOTALS 31,754 19,715.425 100.0000% 23a,585,100 65.528 27M7 38,519 22,010 49,020 100.0% 24783DO a5,528 27,007 38,519 22A10 49,02a PERIOD: APRIL,1992 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,66 13,920 7,457.909 33.4742% 89.495.628 21,465 10,218 11.248 a.485 1a.701 31.8% RES SPACE HT 3&4 589 475,900 2.1360% 5,710,800 1,319 a52 007 384 1.036 2.0% RES WTR HT 33 1.011 1,187,403 5.3299% 14,249,91a 3.146 1,027 1.519 87a 2.502 4.7% RES WTR HT SPHT34 351 04a,115 2.0000% 7,753,380 1.849 $85 784 441 1,328 2.5% TOTALRES 15,851 9,787.477 43.8401% 117,209,724 27,579 13,380 14,198 a,1a5 21ACO 40.8% IRRIGATION 5,20,21.22,23 5,329 2AQ5,759 12.0996% 32,349,108 5.681 3,893 1,988 1.148 4,839 9.2% GEN SVC 0.7 1,604 1,531,708 a.8749% 18,380,498 4,143 2A98 2.045 1,179 3,277 6.2% SCH d CH SMALL a6 41 52,a10 0.2362% 631,428 1a3 72 01 52 124 0.2% TOTAL GEN SVC SCH d CHRCH 1,545 1,584,327 7.1111% 19,011.924 4,308 2,170 2,136 1,231 3,402 6.4% LARGE POWER 8,77 106 2,780,190 12.4785% 33.362,280 11.120 3,808 7,312 4,215 8,024 15.2% SCH d CH LG 58 22 342.000 1.5350% 4,104,000 11951 4a8 1,493 $55 1,323 2.5% OTHER LP 78 2 105,428 0.4732% 1.205,13a 305 144 224 129 273 0.5% TOTAL LOPWR 130 3,227.618 14AB08% 38,731,416 13,439 4,421 9,018 5,199 9,620 18.2% GINS 9 19 54,720 0.2450% a50,640 375 75 300 173 248 0.5% OILFIELDSECDRY 10 912 3,371,842 15.1341% 40,4a2,104 12,790 4,a10 8,177 4,714 9.333 17.7% OILFIELD PRI 11.12 21 521,584 22411% 0.259,008 740 714 32 18 733 1.4% OTHER PRIMARY 08 a 471,772 2.1175% 5,001,264 2,554 040 1,908 1,100 1,740 3.3% TOTAL PRIMARY 26 993,350 4.4586% 11.920,272 3.300 1,3a1 1,939 11118 2,479 4.7% PUB d OS LITES 18,19 27 31,050 0.1394% 372,000 95 43 52 30 73 0.1 % SECRTYLITES 7,024 553,605 2.4848% 8,643,280 1,685 755 927 534 1,293 2A% TOTALS 30,953 22,279.754 100.0000% 267A57,048 69,255 30,520 38.735 22031 52.851 100.0% 69,255 30,520 38,735 22,331 52.851 Page 2 `-I -- -] 7-1 -1 . _1 --i Tl -�l -A � --I ..� ,.� .__. � '--1 I -_-1 -1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: MAY,1992 or KWH/MO. %KWH KWM/YR. N-C AVG UNUSED EXCESS COIN. %0 RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTUL 1.2,66 13,895 8.713,385 33.9818% 104,580,820 24.628 11,936 12,692 7,310 19.248 33.4% RES SPACE HT 3d4 NN9 348.710 1.3600% 4.184,520 1.002 478 524 302 779 1.4% RES WTR HT 33 1,074 1,281,414 4.9975% 15.370.968 3,387 1,755 1,631 940 2095 4.7% RES WTR HTSPHT34 354 572,472 2.2328% 6,809.084 1.487 784 703 405 1.189 2.1% TOTAL RES 15,902 10,915,981 42.5719% 130,991,772 30,503 14,953 15,550 8,058 23.910 41.5% IRRIGATION 5,20,21,22.23 5,313 4,278,184 16.0789% 51,314.208 9.012 5,858 3,154 1,817 7,675 13.3% GEN SVC 0.7 1,609 1,770,623 6.9288% 21,319,476 4,728 2,434 2,292 1,320 3,754 6.5% SCH A CH SMALL 58 42 57.933 0.2259% 895.190 178 79 98 57 136 0.2% TOTAL GEN SVC SCH & CHRCH 1,651 1,834,556 7.1547% 22,014,672 4,004 2,513 2,391 1,377 3.890 0.8% LARGE POWER 8,77 11e 3,592,800 14.0118% 43,113.600 14,831 4,922 9,909 5,708 10,829 18.5% SCH 5, CH LG 58 25 582,000 2.2191% 6,828,000 2,750 779 1,971 1,135 1,914 3.3% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LGPWR 142 4,181,800 18.2308% 49,941,000 17,581 5,701 11,850 6,843 12.544 21A% GINS 9 18 15,080 0.0612% 138,180 107 21 Be 49 71 0.1% OILFIELD SECDRY 10 890 3,339,030 13.0244% 40,075.500 11,922 4,575 7,347 4,232 8,807 15.3% OILFIELD PRI 11.12 19 509,858 1.9884% 81118,296 5eO 698 (138) -(80) 619 1.1% OTHER PRIMARY 88 1 980 0.0038% 11,780 73 1 72 4f 43 0.1% TOTAL PRIMARY 20 510,838 1.9922% 6,180,056 633 700 (e7) (38) 061 1.1% PUB d OS LITES 18.18,19 27 29.808 0.11e2% 357,672 0 0 0 0 0 0.0% SECRTY LITES 7.067 558,825 2.1718% 8.681,900 0 0 0 0 0 0.0% TOTALS 31,030 25,041,300 100.0000% 307,095,000 74,662 34,321 40,341 23,236 57.557 100.0% 74,662 54,321 40,341 23.236 57,557 PERIOD: JUNE,1992 # OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,56 14,052 9,703,378 42.5820% 118,440,538 27,124 13,292 13,832 10,848 24,138 39.8% RES SPACE HT 3&4 575 376,588 1.8528% 4.519,032 1.073 518 557 437 953 -1.8% RES WTR HT 33 1,223 1,358,488 5.9018% 16.301,858 3,617 1,861 1,756 1,377 3.238 5.3% RES WTR HT SPHT34 443 $78,783 2.5399% 8,945,398 1,530 793 737 578 1,371 23% TOTAL RES 16,293 12.017,235 52.7361% 144.200,820 33,344 18,482 16.882 13,238 29.700 49.0% IRRIGATION 5.20,21,22.23 5.499 538,514 23032% 8,462,168 1,135 738 397 312 1,049 1.7% GENSVC 8,7 1,589 1,7e8,955 7.7828% 21,227,4eO 4,701 2,423 2,278 1,786 4,210 8.9% SCH A CH SMALL Be 43 65,751 0.2885% 789,012 109 90 109 85 175 0.3% TOTAL GEN SVC SCH S CHRCH 1,632 1,834,706 8.0514% 22A16,472 4,900 2513 2,387 1,972 4,385 7.2% LARGE POWER 8,77 116 3,624,285 15.4659% 42,291,420 13,001 4,828 9,073 7,115 11.942 19.7% SCH A CH LG 58 20 578,700 2.5398% 8,944.400 2,770 793 1,977 11550 2,343 3.9% OTHER LP 78 0 0 0.D000% 0 0 0 0 0 0 0.0% TOTAL LGPWR 142 4,102.985 18.0054% 49,235.820 18,671 5,621 11,050 81865 14,288 23.8% GINS 9 19 12,800 0.0582% 153.600 88 18 70 55 73 0.1% OILFIELD SECDRY 10 910 3,223,104 14.1442% 38,677,248 11.987 4,415 7,572 5,937 10,353 N n 17.196p, O OILFIELD PRI 11.12 19 469,760 2.0615% 5,037,120 543 844 (101) (79) 555 0.9%0=r N OTHER PRIMARY 88 0 0 0.0000% 0 0 0 0 0 0 0.0, _p_ TOTAL PRIMARY 19 462,780 2.0615% 5.637,120 543 044 (101) (79) 555 0.9%Cu PUB & OS LITES 10,18,19 27 30,387 0.1333% 354,644 0 42 (42) (33) 9 0.0% (D SECRTY LITES 7,087 558,002 2.4487% 8,696,024 0 704 (764) (599) 165 0.3%0 TOTALS 31,e28 22.787,493 100.0000% 273,449,918 88,667 31,216 37,452 20,367 00.563 100.0%- n 88,067 31,216 37,452 29,367 80,583 v cn O Pegs 3 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: JULY, 1992 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,68 14,000 12,071,835 44.8189% 152,002,020 34,338 17,359 18,979 15,590 32,948 41.8% RES SPACE HT 3&4 590 620,336 2.2153% 7.518,032 1,088 858 830 702 1,820 2.1 % RES WTR HT 33 1,239 1,539,154 5.4438% 18,409,648 4,045 2,108 1,937 1,778 3,887 4.9% RES WTR HT SPHT34 441 700,692 2.4783% 8,408,304 1,811 "0 851 781 1,741 2.2% TOTAL RES 16,776 15,538,017 54.9553% 186,456,204 41.882 21,285 20.597 18,911 40,198 51.0% IRRIGATION 5,20,21,22,23 5,318 2,854,003 10.0943% 34,248.036 6,015 3,910 2.105 1.933 5,843 7.4% GEN SVC 6,7 1,830 1,991.082 7.0422% 23,892,984 5,235 2,728 2,507 2.302 5.030 6.4% SCH 3 CH SMALL 58 43 55,418 0.1900% 064,992 171 78 95 87 183 0.2% TOTAL GEN SVC SCH & CHRCH 1,073 2,048,498 7.2382% 24A57,978 5,400 2,803 2,002 2089 5,193 5.0% LARGE POWER 8,77 119 3,493,209 12.3551% 41,918,508 13.714 4,785 8,929 8,198 12,983 16.5% SCH Q CH LG 58 20 427,520 1.5121% 5.130,240 1.953 586 1,307 1,255 1,841 22% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LGPWR 145 3,920,729 13.8072% 47,048.748 16,007 5,371 10,290 9,453 14,824 18.3% GINS 9 19 28,,320 0.1002% 330,940 194 39 155 142 181 0.2% OILFIELD SECDRY 10 880 2A44,434 10.0005% 34.133,208 12,744 3,896 8,848 8.123 12,020 15.2% OILFIELD PRI 11.12 19 452,159 1.5992% 5.425.908 535 619 (84) (77) 542 0.7% OTHER PRIMARY 88 1 11900 0.0009% 23,520 84 3 81 75 77 0.1% TOTAL PRIMARY 20 454,119 1.8002% 5,449,428 819 822 (3) (3) 819 0.8% PUB Q OS LITES 10,18,19 27 28,935 0.0953% 323,220 0 0 0 0 0 0.0% SECRTY LITES 7,144 560,334 1.9818% 6.724,008 0 0 0 0 0 0.0% TOTALS 31,502 28,273,389 100.0000% 339,280,808 82,527 37.928 ",000 40,950 78.876 100.0% 82,527 37,926 44,800 40,950 78,878 PERIOD: AUGUST,1992 PROF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,88 14,031 13,095,882 32.9438% 157,147,944 35,380 17,039 17,420 18,135 34,074 32.7% RES SPACE HT 384 580 678,103 1.7058% 8,137,236 1,808 929 879 814 1,743 1.7% RES WTR HT 33 1,134 1,556.419 3.9153% 18,077,028 4.048 2,132 1,914 1,773 3,905 3.8% RES WTR HTSPHT34 376 724,020 1.8214% 8.688,240 1,936 992 844 782 1.774 1.7% TOTAL RES 18,121 18,054,204 40.3851 % 192.050,"0 43,050 21 R92 21 P55 19,503 41,495 39.9% IRRIGATION 5,20,21,22,23 5,307 13,708,323 34.6302% 165,222,300 29,017 18,801 10,150 9,400 28,207 27.2% GEN SVC 6.7 1,620 2A28,191 5.1021% 24,338,292 5,320 2,778 2.541 2,354 5,132 4.9% SCH Q CH SMALL 50 42 54,878 0.1381 % 658,530 189 75 94 87 102 0.2% TOTAL GEN SVC SCH A CHRCH 1,008 2.083,009 5.2402% 24A90,828 5,489 2.854 2A30 2.441 5.295 5.1 % LARGE POWER 8,77 117 3,470,830 8.74tgs% 41,721,9?O 13,008 4,763 8,905 8,248 13,011 12.5% SCH a CH LG 58 20 428,820 1.0737% 5,121.840 2.024 585 1,439 1,333 1,918 1.8% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LG P WR 143 3,903,650 9.8201 % 46,843,800 15,092 5,347 10,345 9,681 14.928 14.3% GINS 9 18 100,230 0.2521% 1,202,750 087 137 549 509 $46 0.6% OILFIELD SECDRY 10 $78 2,005,789 7.3098% 34,809,488 13,595 3,981 9,814 8.905 12,885 12.4% OILFIELD PRI 11.12 23 347,081 0.8751% 4,174,572 587 477 110 102 579 0.8% OTHER PRIMARY 68 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 23 347,881 0.8751% 4,174,572 587 477 110 102 579 0.0% PUB 8; OS LITES 18,10 27 27A75 0.0090% 332,100 0 0 0 0 0 0.0% SECRTYLTTES 7.164 500,784 1.4107% 8,729,408 0 0 0 0 0 0.0% TOTALS 31,439 39,751.807 100.0000% 477,021,084 108,110 53,040 54,400 80,448 104.096 100.0% 108.110 83,048 54,408 50,448 104,090 "0 N m Ai c' O (D (D a .A C (D O -h c*) O Page 4 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: SEPTEMBER.1992 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %Of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,88 14,097 11,838,281 33.3293% 142,059,132 32,355 18,217 18,138 11,462 27,678 33.1% RES SPACE HT 3rk4 all 599.111 1.a867% 7,189,332 1,a29 821 808 574 . 1,395 1.7% RES WTR HT 33 1,257 1.487,758 4.1888% 17.853.090 3,931 2038 1.893 1,345 3.383 4.0% RES WTR HT SPHT34 469 683,050 1.9231% 8,10a,a00 1,781 938 845 a00 1.538 1.8% TOTAL RES 18.434 14.808,180 41.1275% 175,298,100 39,697 20,011 10.685 13,901 33,992 40.7% IRRIGATION 5.20,21,22.23 5,544 10,405.729 29.2962% 124,868,748 21030 14,254 7,675 5,451 19,708 23.0% GENSVC 6,7 1,627 1,981,817 5.5790% 23.781,804 5,212 2,715 2,497 1,774 4.489 5.4% SCH Q CH SMALL 58 39 67,881 0.1905% 811,932 205 93 112 a0 172 0.2% TOTAL GEN SVC SCH & CHRCH 1,aa6 2.049.478 5.7701% 24093,736 5,417 2,808 2.609 1,853 4,001 5.0% LARGE POWER 8,77 119 3,586,412 10.0972% 43,03a,944 14,295 4,913 9,382 8.683 11,57a 13.0% SCH Q CH LG 58 24 672,440 1.8932% 8,069,280 3,300 921 2,388 1,a9a 2,817 3.1% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LG PWR 143 4,258,852 11.0903% 51,106.224 17,004 5,a34 11,770 8,359 14.193 17.0% GINS 9 - l a 21 A40 0.0815% 282,080 150 30 120 85 115 0.1 % OILFIELD SECDRY 10 882 3,128.403 8.8021% 37,518,83a 12.749 4,283 8,45a 8,013 101296 12.3% OILFIELD PRI 11,12 21 452,080 1.2744% 5,431.020 a81 820 (39) (28) 592 0.7% OTHER PRIMARY as 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 21 452,aa0 1.2744% 5,431,920 581 020 (39) (28) 592 0.7% PUB S OS UTES 18.10 27 30,020 0,0845% 360.312 0 0 0 0 0 0.0% SECRTY LITES 7,198 505.860 1.5931 % 0,790,320 0 0 0 0 0 0.0% TOTALS 31,933 35,519,028 100.0000% 420,228,336 98,127 47,840 50,287 35,714 83,554 100.0% 08,127 47,840 50,287 35,714 93,554 PERIOD: OCTOBER,1991 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. % RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1.2,08 13,917 0.881.803 42.0122% 118,581,630 27AN 13,537 13,998 7,410 2DR47 39.8% RES SPACE HT 3Q4 572 420,481 1.8132% 5,045,772 1,183 576 007 321 897 1.7% RES WTR HT 33 1,142 1,260,609 5.5222% 15,367,308 3.407 1.754 1,853 875 2,829 5.0% RES WTR HT SPHT34 398 571.973 2.4665% 8,8a3,678 1,498 784 715 378 1,102 2.2% TOTAL RES 10,029 12.154,868 52.4141% 145.858,392 33.023 la,651 16.972 8.985 25.835 48.7% IRRIGATION 5,20,21,22,23 5,522 495,199 2.1354% 5,942,358 1,044 an 385 193 872 1.7% GENSVC 6.7 1,531 1,747,391 7,5351% 20068,692 4,632 2,394 2,238 1,185 3,578 8.8% SCH Q CH SMALL ae 38 09,884 0.3014% 838,608 211 98 115 81 157 0.3% TOTAL GEN SVC SCH Q CHRCH 1,509 1,817,275 7.8384% 21007,300 4,843 2,489 2A53 1,246 3,735 7.1 % LARGE POWER 8,77 113 3,838,538 10.5525% 40,0032,432 13,677 5,258 8,419 4,457 9,715 18.5% SCH 8. CH LG 58 24 712.780 3.0730% 8,553,120 3,321 978 2,345 1,241 2,218 4.2% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LGPWR 137 4,551,290 19.8281% 5015,552 10,998 8,235 10,783 5,898 11,933 22.7% GINS 0 20 207,590 1.1539% 3.211,080 733 367 367 194 561 1.1% OILFIELD SECDRY 10 a99 2,796,681 12.0594% 33,558,072 13,833 3,831 10,002 5,295 9.128 17.3% W n O OILFIELD PRI 11.12 21 548,088 2.3834% 0,5715,792 820 751 a9 37 787 1.5% ca to OTHER PRIMARY 68 0 0 0.0000% 0 0 0 0 0 0 0.0% rD a TOTAL PRIMARY 21 548,060 2.3034% 0,576,792 820 751 09 37 787 1.5% PUB & OS UTES 18,19 26 30,077 0.1297% 360,924 0 0 0 0 0 0.0% -' SECRTY LITES 6,714 529,105 2.2818% 6,349,250 0 0 0 0 0 0.0% O rD TOTALS 30,937 23,190,055 100.0000% 278,280,660 71.893 31,001 40,892 21048 52,849 100.0% -h C7 71,893 31,001 40,892 21 A48 52,049 1 V Ul O Page a '-I SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS PERIOD: NOVEMBER,1991 #OF KWHJMO. %KWH KWHM. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1.2.66 13,a59 7,825,030 37.7993% 93.907,560 22.387 10,720 11,687 a,301 19,021 33.8% RES SPACE HT 3&4 577 409,205 1.97e8% 4,911,180 1.158 561 595 423 984 1.7% RES WTR HT 33 1,145 1,094,486 5.2888% 13,133.832 2000 1,499 1.467 1,044 2,543 4.5% RES WTR HTSPHT34 3" 551,206 2.ea27% 8,a16,192 1,449 755 094 494 1.249 2.2% TOTAL RES 15077 9,BaO,647 47.7255% 118,587.764 27ASO 13,535 14,423 10.262 23,797 42.3% IRRIGATION 5,20,21,22.23 5,517 437,721 2.1143% 5,252,652 922 am 323 230 829 1.5% GEN SVC 8,7 1,004 1,616,218 7.3230% 18,194,ala 4,100 2A77 2A29 1,444 3,521 a.3% SCH A CH SMALL 50 39 51,025 0.2465% 812,300 159 70 90 84 134 0.2% TOTAL GEN SVC SCH h CHRCH 1,043 1,567,243 7.5701% 18,800,918 4,205 2,147 2.119 1,507 3,a54 6.5% LARGE POWER 8,77 119 3,394,411 10.3957% 40,732,932 13.087 050 8,417 5,989 10,038 18.9% SCH & CH LG 58 24 544,160 2A284% 8,529,920 2,902 745 2,217 1,577 2A22 4.1% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LG PWR 143 3,038,571 19.0241 % 47,202.852 18,029 5,395 10,834 7.500 12,981 23,0% GINS 9 20 817.580 3.9491% 9,810,900 2,240 1.120 1.120 797 1.917 3.4% OILFIELD SECDRY 10 004 3,058,111 14.7713% 30,897.332 13,614 4,180 9,425 0,705 10,895 19.4% OILFIELD PRI 11,12 21 438,030 2.1158% 5,260,300 812 ON 212 151 751 1.3% OTHER PRIMARY as 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 21 438,030 2.1158% 6,25a,360 812 "0 212 151 751 1.3% PUB A OS LITES 18,19 20 30,429 0.1470% 305,148 93 42 51 38 78 0.1% SECDTY LITES a,805 634,757 2.5830% a,417,084 1.028 733 80 837 1.370 2.4% TOTALS 31.050 20,703,089 100.0000% 248,437.008 67,562 28AM 39,202 27A91 50,251 100.0% 67,502 25MO 39,202 27,891 50.251 PERIOD: DECEMBER,1091 #OF KWH/MO. %KWH KWH/YR. N-C AVG UNUSED EXCESS COIN. %of RATE CONS. SALES SALES SALES DEMAND DEMAND DEMAND DEMAND DEMAND TOTAL RESIDENTIAL 1,2,80 13,915 8,889,030 31.3353% 100,ae8,432 25A71 12.177 12,894 4.252 18.429 27.5% RES SPACE HT 3h4 578 930.431 3.3011% 11.237,172 2,404 1.283 1,121 370 t,a52 2A% RES WTR HT 33 1,154 1,381,791 4.8005% 18,341,402 18,949 1,805 17.083 5,634 7.490 12.5% RES WTR HTSPHT34 404 005,938 3.4051% 11,591.258 2.321 1,323 998 320 1,852 22% TOTALRES 18.049 12,153,198 42.8420% 145.838,352 48,745 1e,048 32,09s 10,585 27,233 45.a% IRRIGATION 5.20,21,22,23 5,475 238,100 0.8304% 2,857.272 502 320 17a 58 384 0.0% GEN SVC 8,7 1,586 1.805,248 8.3638% 21482,978 4,78a 2.473 2,313 703 3,236 5.4% SCH h CH SMALL as 41 61,437 0.21aa% 737.244 022 84 538 177 201 0.4% TOTAL GEN SVC SCH 8, CHRCH 11827 1,80a,a85 0.5804% 22,400,220 5.407 2,557 2,850 940 3.497 5.8% LARGE POWER 9,77 112 3,652,352 12.5226% 42,628.224 13,954 4,856 9.088 2A97 7,863 13.2% SCH h CH LO 68 20 531,100 1.8722% a,373,200 2.189 728 1,461 482 1,210 2.0% OTHER LP 78 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL LG PWR 138 4,083,452 14.3948% 49,001,424 18.143 5,594 10,549 3,479 9,073 15.2% GINS 9 20 5.883,380 20.7399% 70,800,560 ta,119 8,059 8.059 2958 10,717 17.9% OILFIELD SECDRY 10 889 3.051,715 10.7578% 3a,820,580 12,977 4,180 8,797 2,901 7,081 11.8% OILFIELD PRI 11.12 21 51a,415 1.8204% 8,10e,980 see 707 (41) (14) 694 1.2% OTHER PRIMARY as 0 0 0.0000% 0 0 0 0 0 0 0.0% TOTAL PRIMARY 21 518,415 1.8204% 6,10a,980 am 707 (41) (14) 094 1.2% PUB h OS LITES 18.19 26 33,974 0.1198% 407,688 103 47 57 19 as 0.1 % SECRTY LITES a,891 540.608 1.905a% 6,480,818 1,840 741 905 298 1,039 1.7% TOTALS 31,136 29.367,491 100.0000% 340.409.892 102,309 35,800 83.448 20A24 59,764 100.0% 102,308 38,800 83,448 20024 59,784 Page a `m-_I ------- ------ 1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. AVERAGE AND EXCESS DEMAND CALCULATIONS YEAR'S TOTALS AVG a# OF *OF ANNUAL %KWH N-C % AVG % COIN. % of RATE CONS. CONS. KWH SALES SALES DEMAND OF TOTAL DEMAND OF TOTAL DEMAND TOTAL RESIDENTIAL 1.2.00 108,077 14,000 110,184,233 30.570094% 324.113 33.817892% 159,156 30.909025% 268,251 34.729017% RES SPACE HT 3A4 6.937 578 7.813,393 2A59340% 20,753 2.152494% 10,703 2A82133% 18,847 2.197300% RES WTR HT 33 13,718 1,143 16,335,575 5.141778% 58,487 0.0003e2% 22,378 3.189432% 40,e82 5.300490% RES WTR HT SPHT34 4,821 402 9,038,002 2.844797% 22.802 2.3e5O78% 12,381 2An 163% 18,825 2.455538% TOTAL RES 193,553 10,129 149.371.203 47.016009% 420.157 44.201826% 204018 47.451753% 342,808 44.088500% IRRIGATION 5.20,21,22.23 05.322 5,444 30,001,843 11.331923% 75.874 7.809716% 49,318 11.430947% 09.972 9.126031% GENSVC 6.7 19,140 1,596 21.331.312 8.714234% 54.834 5A87400% 29,221 0.770401% 45,688 5.959474% SCH d CH SMALL 50 488 41 705,094 0.222124% 2,599 0.259523% 9" 0.224183% 1,860 0.243380% TOTAL GEN SVC SCH & CHRCH 19,032 1,830 22,037,000 8.936358% 57,432 5.95e989% 30,188 7.000044% 47,554 e.202863% LARGE POWER 8.77 1,304 114 40.485.371 12.743150% 159.805 10.554555% 55,459 12.861260% 121,701 15.882222% SCH d CH LG 58 298 25 0,196,820 1.950445% 29.380 3.047353% 8,489 1.988522% 21.814 2A45301% OTHER LP 78 4 0 103,275 0.000835% 737 0.078443% 265 0.001399% 530 0.009888% TOTAL LGPWR 1,886 139 46,875,20e 14.754430% 189.722 19.678352% 84,213 14.821180% 144,111 18.797411% GINS 9 231 19 12,M,560 3.997314% 38,799 3.816847% 17,397 4.034301% 2eA71 3.400026% OILFIELD SECDRY 10 10,758 897 37.074.314 11.809493% 154.220 15.998012% 50,787 11.777640% 118,742 15.227558% OILFIELD PRI 11.12 245 20 5.731.783 1.804133% 8,148 0.645127% 7.852 1.820854% 8,047 1.049890% OTHER PRIMARY 68 12 1 945,308 0.297545% 5,229 0.542363% 1,295 0.300302% 3,582 OA M69% TOTAL PRIMARY 257 21 e,e77,091 9.101678% 13,377 1.387490% 9,147 9.121156% 11,029 1.316950% PUB d OS LITES 10.18.19 321 27 371.189 0.115835% 598 0.001975% 311 0.072008% 449 0.058512% SECRTY LITES 83,909 6,992 6,595,304 2.075954% 9,937 1.030733% 5.230 1.214305% 7,518 0.980081 % TOTALS 375,849 31,304 317.702.850 100.000000% 904,115100.000000% 431,213100.000000% 708.052 100.000000% 'O Ln (") W n O to S (N (D [D d V C fD O -h e') V CIl O Page 7 SOUTH PLAINS ELECTRIC COOPERATIVE, INC, ALLOCATION OF RATCHET DEMAND JAN92 FEB MAR APR MAY JUN JUL AUG SEP91 OCT NOV DEC TOTAL RESIDENTIAL MONTH PEAK 27,528 24,825 22,338 21,774 24,229 30,989 41,911 43,335 34,741 25,827 24,519 26,551 348,545 ANNUAL PEAK 43,335 43,335 43,335 43,335 43,335 43,335 43,335 43,335 43,335 43,335 43,335 43,335 520,020 EXCESS 15,807 18,510 20,999 21501 19,108 12,388 0 0 0 17,508 18,818 16,784 171,475 IRRIGATION MONTH PEAK 205 89 212 4,888 7,739 1,079 6,018 29,154 19,998 876 846 380 71,484 ANNUAL PEAK 29,154 29,154 29,154 29,154 29,154 29,154 29,154 29,154 29,154 29,154 29,154 29,154 349,848 EXCESS 28,949 29,065 28,942 24,286 21,415 28,075 0 0 0 28,278 28,308 28,774 278,384 TOTAL EXCESS 44,750 47,575 49,941. 45,847 40,521 40,441 0 0 0 45,786 47,124 45,558 407,549 RES RATCHET 3,903 6,784 8,790 8,032 5,834 2,858 0 0 0 8,808 5,462 3,738 51,988 IRRIG RATCHET 7,147 10,621 12,114 9,047 6,539 6,489 0 0 0 10,873 8,217 6,408 77,256 TOTALALLOCATED 11,050 17,385 20,004 17,079 12,373 9,347 0 0 0 17,281 13,879 10,146 129,244 TOTALRATCHET 11,050 17,385 20,904 17,079 12,373 9,347 0 0 0 17,281 13,879 10,146 129,244 RATGWr South Plains Electric Cooperative, Inc. Test year Ended September 30, 1992 Present Rates COST OF SERVICE ALLOCATION - PLANT ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH i CH LG LB POWER Gins Oilfield Sec Oilfield Pri Lighting TRANSMISSION PLANT ---- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------------ 350 LAND 6 RIGHTS 74.617 1 32.902 5.072 4.445 2,331 12,352 2,940 11.936 1,035 915 353 STATION EOPT 1,114.899 1 492.605 87,740 66.415 34,827 184,566 42,554 179,339 15,469 12,183 355/356 POLE i COND 11.0101.853 1 446.915 79.552 60,217 31..577 167.342 38.583 161,696 14.025 11,046 Total z==rrszszazsz se:::s:asxz:a sasxz:zassx:a sss¢arx¢:sxxa x::xzs=zzxx:: s:xz:z:z:::x: as:ss::z=zzz: a:=:=:::::::: :::=:zzzzzssz ::aa=::z:azr: TRANSMISSION PLANT 2.200.369 1011 972.603 173.164 131.077 60.735 364.261 83.985 351,971 30,530 24,044 44.2021 7,870% 5.957% 3.1241 16.555% 3.8171 15.996% 1.3871 1.0931 DISTRIBUTION PLANT ------------------ 360 LAND 112.054 1 49,530 8.818 6.675 3.500 18.550 4.277 17.924 1.555 1.224 362 STATION EOPT 5,046,723 1 2.230,742 397.167 300.636 157,649 835.461 192,626 807,273 701.023 55446. 364/365 1 PH 2,423.431 7 2.047,224 34,377 118,410 0 0 0 0 0 223.420 364/365 3 PH 61453,277 B 44,958 4,652,258 634,80E 22.479 256.261 17.084 906,547 18.882 0 360365 BACKBONE 11,014.009 1 4.869.389 866,780 656.111 344.055 1.823.317 420.389 1.761.799 152.018 120.351 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ACCT 364/365 19.990,717 1021 6.960,571 5,553.415 1.409,329 366,534 2,079,579 437.473 2.568,346 171.700 343,771 34.9941 27.920% 7.0851 1.8431 10.4551 2.199% 12.9121 0.863% 1,728% 366/367 UG 10,629.263 10 2,923,047 3,985,974 1,062,926 425071 1,328,658 531,463 212,585 159039 0 368 REGS 6 CAPCTORS 1,853,128 1 819,116 145,837 110,392 51,888 306.777 70.731 296,426 25,712 20.249 368 TRANSFORMERS 7.800.338 11 4.336.400 2.093.455 791.800 P.M 132,619 121,322 295.659 0 0 Subtotal------------- ------------- ------------- ------------- ------------- ------------- -- TOTAL TRANSFORMERS 9,653.466 1031 5.155.515 2.239,292 902,192 86,971 439.396 192.053 592,085 25,712 20,249 53.406% 23.197% 9.3461 0.901% 4,552% 1.989% 6.133% 0.266% 0.210% 369 SERVICES 1.682.870 12 876,784 522,247 115,162 3,997 18.227 3.038 143,416 0 0 370 METERS 2.069.285 13 913.290 401.200 120.640 16.485 75.170 12,528 556.675 73,308 0 371 INST CONS PREM 1..959,281 14 0 0 0 0 0 0 0 0 1,959,281 Total zzzzazzzz=zxz :z::::zs:s=:x s:::::s:z=:s: _____________ _____________ _______ _____ ===a -------=a sass:¢___--s= ---z------axz __a__z:zzzzzs DISTRIBUTION PLANT 51,043.659 1041 19.009.470 13,108,112 3,917,560 1,060,306 4,795.039 1,373.459 4.898.305 501,736 2,379,672 a 0 CD37.242% 25.680% 7.675% 2.077% 9.3941 2.691% 9.5961 0.983% 4.662% N o_ �c SUBTOTAL xx:=azx::==za PLANT 53.244,029 1051 19,982,072 131.281,276 4,049,637 1,129,041 5,159,300 1,457,444 5,250,276 532.266 2,403,715 -i, 37.529% 24.944% 7.604% 2.121% 9,6901 2.737% 9.061% 1.000% 4.515% v GENERAL PLANT ~ ------------- O TOTAL GENERAL PLANT 4.421.448 104 1,646.617 1,135,437 339.343 91.845 415,351 118,970 424,296 43,461 206,129 Total zazzxzzzz=a:z ==::_=x=s:=s: zzzz__z_z_zz_ xzzz____:x=zx _zzzzz:=zzxzs ____=zzzzsaza azssza:sa:zsz saz==:::zzzz= _:arzxszzzzzs _:zs:azzz-zzz GENERAL PLANT 4.421.448 1061 1.646.617 1.135.437 339.343 91445 415.351, 118,970 424.296 43,461 206,129 - 37.242% 25.680% 7.675% 2.077% 9.394% 2.6911 9.596% 0.9831 4.662% i South Plains Electric C000erative, Inc. Test Year Ended September 30, 1992 Present Rates COST OF SERVICE ALLOCATION - PLANT - ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL -------------------- ------------- ------------------------------ IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER ---------------------------------------------------- Gins Oilfield Sec ------------- Oilfield Fri -------------------------- Lighting TOTAL_____________ ________=__==----------_-- ----:-----_----------- - --------------------------- =___====_-=__ =_=__=_-__-=_ _--=-===_==_= PLANT 57,665,476 1071 21,628.690 14,416.713 4,387,980 1,220.886 5,574,650 1,576,414 5.b14,511 575,727 2.609,845 37.5071 25.001% 7.609% 2.117% 9.667% 2.7341, 9.841% 0.998x 4.5261 -0(NCl) a 0 O tG S N CD CD d N C O CD G N 1 . o-+ O South Plains Electric C000erative. Inc, Test Year Ended September 30. 1992 Proposed Rates COST OF SERVICE ALLOCATION - PLANT ACCOUNTS -------------------- TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH i CH L6 LG POWER - Gins Oilfield Sec ------------- Oilfield Fri Liohtine TRANSMISSION PLANT ------------------ ------------- ---- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- 350 LAND 6 RIGHTS 74.617 1 32,982 5.972 44445 2.331 12.352 2,848 11..936 1.035 815 353 STATION EOPT 1.114.899 1 492.805. 67.740 66.415 34.827 184.566 42,554 178,339 15,469 12,183 355/356 POLE 6 COND 1.010.853 1 446,815 79.552 60.217 31.577 167.342 38.583 161,696 14,025 11.046 Total =____________ -----=------- ------------- ------------- --=------===_ -___- --__------ ------------- _____=_______ TRANSMISSION PLANT 2.200.369 1011 972.603 173.164 131,077 68.735 364,261 83.985 351,971 30.530 14,044 44.202% 7.870% 53571 3.174% 16.555% 3.917% 15.9961 1.3871 1.0931 DISTRIBUTION PLANT ------------------ 360 LAND 112.054 1 49.530 8.818 6.675 3.500 18,550 4.277 17.924 1.555 1.224 362 STATION EOPT 5,046,723 1 2,230,742 397.167 300,636 157,649 035,461 192.626 807,273 70,073 55446 364/365 1 PH 2.423,431 7 2.047,224 34.377 118,410 0 0 0 0 0 223.420 3641365 3 PH 6.453.277 8 44.958 4,652.258 634.909 22.475 256.261 17.094 806.547 18.882 0 3641365 BACKBONE 11.014.009 1 4.968.385 866.780 656.111 344.055 1,023,317 420.389 1.761,799 152.818 120.351 - Subtotal------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ACCT 3641365 19.890.717 1024 6.960.571 5.553.415 1.409,329 366.534 2.079.570 437.473 2,560,346 171,700 343.771 34.994% 27.9201 7.005% 1.843% 10.455% 2.199% 12.912% 0.863% 1.728% 366/367 UG 10,629,263 10 1,923.041 3,985.974 1.0621.926 425,171 1.31B,658 531,463 212.585 159,439 0 368 REGS i CAPCTORS 1,853.128 1 019.116 145.837 110,392 57,888 306,777 70,731 296,426 25,712 20.249 368 TRANSFORMERS 7,800.338 11 4,336,400 2.093.455 791400 29.083 132,619 121,322 295.659 0 0 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ------------- TOTAL TRANSFORMERS 9,653.466 1031 5.155.515 1,239.192 902.192 86,971 439.396 192.053 591.085. 25,712 10.145 53.406% 23.197% 9.346% 0.901% 4.552% 1.909% 6.133% 0.266% 0.2101 369 SERVICES 1..602.070 11 876,784 522,247 115.162 3,997 18,227 3,038 143,416 0 0 370 METERS 2.069.285 13 913.260 401.200 120.640 16.485 75,170 12.526 556.675 73.308 0 ` 371 INST CONS PREM 1.959,291 14 0 0 0 0 0 0 0 0 1.959,291 -0 v, Cn Total=________=_=_ _____________ _____________ ________•--__ -------_:____ ------_-- _----_------- ----- ---_--_--_--= cn to S DISTRIBUTION PLANT 51.043.659 1044 19,009.470 13,108.112 3,917.560 1,060,306 4,795,039 1,373.459 4,890.305 501,736 2,379.672 'D 'D 37.242% 25.680% 7.675% 2.077% 9.394% 2.691% 9.596% 0.983% 4,6611 '-- r- o rD SUBTOTAL =__-______-=_ ==--_=---=_-_ __-____•----- --=------_=== ___-•________ _____________ - ____________ _=--=_=•_---- -h PLANT 53,244,020 1051 19,982,071 13,281,116 4,048,637 1,119,041 5,159,300 1,457.444 5.250.276 532,266 2,403,715 N Aa 37.529% 24,944% 7.604% 2.121% 91690% 2.737% 9.861% 1.000% 4.5157 0 GENERAL PLANT ------------- TOTAL GENERAL PLANT 4.421..440 104 1,646,617 1,135,437 339,343 91,845 415,351 118,970 424.296 43.461 206.129 Total _____________ ________=____ ________::__: ==:___==____° ===___=______ _____________ __==_=_______ ____.__••_--- _=_======__-_ ==_==_======_ GENERAL PLANT 4.421.448 1061 1,646.617 1..135.437 339,343 91.B45 415,351 118.970 424.296 43,461 206.129 %7 7177 74 LOAY 7 L MY 7 A771 0 taAY a ca,r a cocr A ant./ , ,.n• South Plains Electric Cooperative, Inc. Test Year Ended September 30. 1991 Pr000sed Rates COST OF SERVICE ALLOCATION - PLANT ACCOUNTS -------------------- TOTAL DOLLARS A.F. ------------- — - RESIDENTIAL -------------------------- IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER ---------------------------------------------------- Gins Oilfield Sec Oilfield Pri --------------------------------------- Lighting TOTAL --_-_-=--___- PLANT 57.665,476 1071 21,628.690 14.416,713 4.387.980 1,220.886 5.574.650 1.576.414 5,674,571 575.727 2.609,845 37.507Z 25.001% 7.609% 1.117Z 9.667Z 2.734% 9.841% 0.998% 4,526Z �V C/f C ) W 0 CD (a = C/f M (D CL N C O (D N 1 N O F P* Investment: rAccount364 t Account365 Total r SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Account 364 & 365 — Overhead Distribution Une Miles Of Une r to Single Phase (1) 673 Three Phase (2) 1457 Three Phase Backbone (3) 971 Total 3,101 r 1 (1) Allocated by Factor 7 (2) Allocated by Factor 8 (3) Allocated by Factor 1 f k COS Schedule D-3.0 $9,847,391 10,043,327 $19,890,718 Cost Weighted % Of Ratio Miles Total Investment 1.00 673 12.1837% $2,423,431 1.23 1,792 32.4437% 6,453,277 3.15 3,059 55.3726% 11,014,009 5,524 100.0000% $19,890,718 R c: t 4 COS Schedule D-4.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. r, i Account 368 - Transformers ` Total Investment: r-• Regulators, capacitors, Etc. $ 1,853,128 Transformers 7,800,338 Total $ 9,653,466 F E. Regulators and capacitors allocated by Demand 1. Transformers allocated as follows: Number InstElled Kva cost Cost Weighted % Of Consumers Kva Per Cons Per Kva Ratio Kva Total Irwestrnent RESIDENTIAL 16,129 161,290 10.0 $26.00 4.00 645.160 55.5925% $4.336,400 IRRIGATION 5,444 95,270 17.5 21.25 3.27 311,460 26.8380% 2.093,455 GENERALSERVICE 1,596 47,880 30.0 15.50 2.38 114,175 9.8383% 767,422 3 SCH & CH SMALL 41 2,050 50.0 11.50 1.77 3,627 0.3125% 24,378 SCH & CH LARGE 25 3,125 125.0 9.00 1.38 4.327 0.3728% 29,083 r LARGE POWER 114 14,250 125.0 9.00 1.38 19,731 1.7DO2% 132,619 j GINS 19 18,050 850.0 6.50 1.00 18,050 1.5553% 121,322 OILFIELD SECDRY 897 13,455 15.0 21.25 3.27 43,988 3.7903% 295,659 OILFIELD PRI 21 0 0 0 0.0000% 0 SECRTY LITES 7,019 0 0 0 0.0000% 0 �.. 1 f TOTAL 31,305 355,370 1.160,517 100.0000% $7,800,338 C RESIDENTIAL r• IRRIGATION 4 GEN SVC L, SCH & CH SMALL r+ SCH & CH LARGE LARGE POWER GINS OILFIELD SECDTY OILFIELD PRI SECRTY LITES r'+ TOTALS r L 6 1` L COS Schedule D-5.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Account 369 — Services Number Cost Cost Weighted % Consumers Per Cans Ratio Consumers TOW Investment 16,129 85 1.00 16,129 52.1005% $876,784 5,444 150 1.76 9,607 31.0331 % 522,247 1,596 110 1.29 2,065 6.6718% 112,277 41 110 1.29 53 0.17141/a 2,884 25 250 2.94 74 0.2375% 3,997 114 250 2.94 335 1.0831% 18,227 19 250 2.94 56 0.180596 3,038 897 250 2.94 2,638 8.5221 % 143,416 21 0 0 0.0000% 0 - 7019 0 0 0.00000/0 0 31,305 30,957 100.0000% $1,682,870 RESIDENTIAL IRRIGATION GEN SVC SCH & CH SMALL SCH & CH LARGE LARGE POWER GINS OILFIELD SECDRY OILFIELD PRI SECRTY LITES TOTALS COS Schedule D-6.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Account 370 — Meters Number Cost Cost Weighted % Consumers Per Cons Ratio Consumers Total Investment 16,129 $65 1.00 16,129 39.3025% $813,280 5,444 95 1.46 7,957 19.3883% 401,200 1,596 95 1.46 2,333 5.6840% 117,618 41 95 1.46 60 0.1460% 3,022 25 850 13.08 327 0.7966% 16,485 114 850 13.08 1,491 3.6326% 75,170 19 850 13.08 248 0.60549/6 12,528 897 800 12.31 11,040 26.9018% 556,675 21 4,500 69.23 1,454 3.5427% 73,308 7019 0 0.00 0 0.0000% 0 31,305 41,038 100.0000% $2,069,285 ..�.`1 7-1 -1 °mil . � . � .�1 .� � � � --A South Plains Electric C000erative. Inc. Test Year Ended Seotember 30. 1992 Present Rates COST OF SERVICE ALLOCATION - REVENUES ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. ---- RESIDENTIAL -------------------------- IRRIGATION GEN SERVICE SCH 6 CH LG ------------- LG POWER Gins Oilfield Sec Oilfield Pri ------------- Liahtino ENERGY REVENUE ------------- ------------- ------------- ------------- ------------- -------------- BASE REVENUE 24,870.823 15 11.034.499 3.207,232 1.963.342 561,096 3.090.714 853.928 31.166,515 410.699 582.797 PCRF REVENUE -4.488.127 16 -2.083.368 -460.402 -312.709 -95.344 -504.642 -21B.887 -535,919 -96.930 ` -99.927 Total ENERGY REVENUE 20,382.696 1081 8,951,131 2,746.830 1,650,633 465.752 2,506,072 635.041 2,630,597 313.769 482,870 43.915% 13.476% 8.098% 2.295% 12.2951 3.1161 12.906% 1.539% 2.3691 OTHER REVENUE ------------- OTHER REVENUE 127.704 17 56,659 16,460 10,081 2,881 15,870 4.385 16,259 2.109 2,992 Total OTHER REVENUE 127,704 109# 56.659 16.460 10.091 2,881 15,B70 4.385 16,259 2.109 2.992 44.3671 12.896% 7.894% 2.2561 12.4271 3.433% 12.732% 1.651% 2.343% TOTAL __-__-_____ REVENUES 20,510,400 1101 9,007,790 2,763.298 1,660,714 469.633 2,521.942 639.426 2.646,956 315.878 405.063 43.918% 13.473% 8.0971 1.1851 12.2961 3.119% 12.905% 1.5407. 2.369% (nn 0 O S N fD GL C fD m r O South Plains Electric C000erative. Inc. Test Year Ended Seotesber 30. 1992 Proaosed Rates COST OF SERVICE ALLOCATION - REVENUES ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH & CH LG LG POWER Gins Oilfield Sec Oilfield Fri Liahtinq ENERGY REVENUE -------------- ---- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- BASE REVENUE 25,794,875 15 11.557.942 3.373.1420 1.963.342 561,096 3.150,396 883,422 3.166,515 419,386 619.356 PCRF REVENUE -4,488.127 16 -2.083,368 -460.402 -312,709 -95.344 -584,642 -218,887 -535.918 -96.930 -99.927 Total - s=-=====_==__ _____________ -- - _____________ - - -- - - ____=-__=_=== -- - -=-===s=-===_ - -- - ---- ----- - ----- -- - ENERGY REVENUE 21.306.748 1091 9.474.574 2.913,01E 1,650.633 465.752 2,665,754 664.535 2.630,597 322.456 519.429 44.4671 13.672% 7.747X 2.1861 12.5111 3.119% 12.346% 1.513% 2.438% OTHER REVENUE ------------- OTHER REVENUE 127,704 17 56.659 16.468 101081 2.881 15.870 4.385 16,259 2.109 2.992 Total=_-_-•_-_---- _•-----•---- ------------- ------- ----- ------------- ----F....=_.. ---.-------- ----------_-- -_----__-- _ _-_--------_- OTHER REVENUE 127.704 1091 56.659 16.466 10.081 2,861 15.870 4.385 16.259 2.109 2.992 44,3671. 12.896% 7,8941 2.256% 12.4271 3.4331 12.732X 1.651X 2.3437 TOTAL -------------==xzz===ZZ=Z= =====Z=Zz===Z ====_=_==__- __=____-=_ -=- REVENUES 21.434.452 1101 9.531,233 2.929.486 1,660,714 468,633 2,681.624 668,920 2,646.856 324065 522,421 44.4671 13.6617. .7.749% 2,186% 12,511% 3,121% 12.349% 1.514% 2.4371 tN n 0 O fD G. C fD m N O -� south Plains Electric U"aerative. Inc, test Year Ended September 30. 1992 Present Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. RESIDENTIAL ------------- IRRIGATION GEN SERVICE SCH & CH LG LG POWER Gins Oilfield Sec Oilfield Pri Lighting TRANSMISSION EXP ---- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ---------------- 571 MAINT TRANS LINE 2,205 101 975 174 131 69 365 84 353 31 14 Total xxx=====_____ ____-----x=== ..____ _____________ ------------- ------==::=xa - ----- :-______-___• -------- -_.-..-_sxzzz ------------- ----- - .--..s-•-__=z -___ zz -- - zzzaaazz a__-z TRANSMISSION EIP 2.205 1111 975 174 131 69 365 84 353 31 24 44.202Z 7.010Z 5.957Z 3.124% 16.555% 3,8171 15.9961 1.307% 1.093Z DIST OPERATIONS --------------- 580 SUPV 6 ENGR 109.846 104 40.908 26,209 8.431 2.282 10,319 2.956 10.541 11080 5.121 582 STATION EXP 27.233 1 12.037 2.143 1.622 851 41508 1,039 4.356 378 298 563 OH LINE EXP 263,841 102 92,329 73.663 18.694 4.862 27.585 5.03 34,060 2.278 4,560 564 UG LINE EIP 557 10 153 209 56 21 70 28 11 8 0 586 METER EXP 321,018 13 126,168 62,240 18.715 2.557 11.661 1.944 06,360 11.373 0 587 CONS INST EIP 6,066 14 0 0 0 0 0 0 0 0 6.066 588 M1SC DIST EIP 121,753 104 45,343 31.266 9044 2,529 11,437 3.276 11,684 1,197 5.676 Total =_=----=_===_ ---•--====___ _____________ ____________' --=_--_---___ =-__=-___-__- _-__--_____-= -_-=•====-_-- ----_-_---___ =_==-_===__-- DIST OPERATIONS 850,314 112t 316.938 197.731 56,863 13,103 65,580 15,046 147.020 16,313 21.721 37.2731 23.2541 6.687Z 1.541Z 7.712% 1.769% 17.290% 1.918Z 2.5541 DIST MAINTENANCE ---------------- 590 SUPV & ENGR 69.182 104 25,764 17,766 5,310 1.437 6,499 1.862 6,639 680 3,225 592 MAINT STN EOPT 194,779 1 861096 15,329 11.603 6.084 32,245 7.434 31.157 2,703 2,128 593 KAINT ON LINES 306.163 102 107.639 96.038 21.934 5.679 32.218 6.718 39,791 2.660 5.326 594 MAINT UG LINES 164.576 10 45,258 61.716 16.458 6.583 20,572 8.229 3.292 2,469 - 0 575 MAINT TRASF 165.301 11 91.895 44.363 16.779 616 2.810 2.571 6.265 0 0 596 MAINT ST LT SYST 5.174 14 0 0 0 0 0 0 0 0 5414 597 MAINT METERS 72.542 13 28.511 14.065 4.229 578 2,635 439 19.515 2,570 0 598 MAINT MISC DIST 35,449 104 13.202 9.103 2,721 736 3,330 954 3.402 348 1,653 Totalzzzz=zxz===== ------------- =Z=ZZZ=Z===M= -----:=:zz=z= ------------- ------------- --••--•----•= ---------•zzz =u:==:=z=_== a-------_---_ DIST MAINTENANCE 1.015,166 11311 398.565 248,380 78.934 21.714 100.310 28,266 110,060 11,430 17,506 39.261% 24.4671 1,775Z 2.139% 9.081% 2.794% 10.B421 1.126% 1.724Z SUBTOTAL z zzz=zz=z==s: ---------•--- ------------- --•-------- ------------- ------------= ------------- ---- - ----°x=:===_= -- -==z --__:____- :==z==z:=:zz= _____________ '- •- -- zss==z _==--=_ -- --- --_____----_- � EXPENSES 1.867,685 1141 716,478 446.2B4 135.928 34.886 166.255 43.396 257,433 27.773 39.251 °i 0 O tG S CA 38.362% 23.8957. 7.278% 1.068% 8,902% 2.324Z 13.784% 1.487Z 2.102% rD rD C. CONS ACCTS ---------- o M 902 METER READ EXP 205.808 6 86,900 29,331 44,099 11010 15.355 256 9.666 283 18.908 903 CUST RECORDS 582,960 9 291.911 90,528 74,068 3.393 61,e97 He 32.469 950 19.055 W 904 UNCOLL ACCTS 72,000 15 31.944 9.295 5.684 11624 8.947 2.472 9467 11189 1,687 0 Total xz====z:z=zu :z=z==z:==:=z zzzzzzzz=zzz= ==z== :z==s== ==_=.•••••••• :x=z==x=:=zz= ••••-••s-:-z- zz-•--•-••••= .=._z=x..-.xx =az==zz===x=z CONS ACCTS 860,768 1151 410,755 137,144 123.851 6.028 86,200 3.416 51,301 2,422 39.651 47.7201 15.933Z 14.388Z 0.700% 10.014% 0.397% 5.960% 0.281% 4.606% South Plains Electric C000erative. Inc. Test Year Ended Seotember 30, 1992 Present Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oilfield Sec Oilfield Pri Lighting -------------------- ------------- ---------------------------------•---------------------------------------------------•---------------------- ------------- CUSr SERV EXP 908 CUST ASSIST 13.513 9 6.766 2.284 1,717 79 1,435 16 753 12 442 909 ADVERT i PROM 9.343 9 4,678 1,579 1.187 54 992 11 520 15 305 910 MISC CUST ASSIST N ,233 9 17.142 5,786 4.349 199 3,635 40 1,907 56 1.119 912 DEMO & SELL 64,921 9 32.501 10,973 8,249 378 6,893 77 3,616 106 2,122 Total=ZZZXZZZXZZZZ ----- -------- ------------- ------------- ------------- =:x:x:x=====_ CUST SERV EXP 122,010 1161 61.015 20,621 15,501 710 12,955 144 6,796 199 3.988 50.0741 16.901% 12.706% 0.5821 10,6181 0.118% 5.570X 0.163% 3.2691 SUBTOTAL xxx:x:::xx=:: xx::--------- --------- ------------- ------------- ::xx:xx::::xx x:xxx=.=:xxx: ---- ----xxxx::x:x :xxxxx:xxx:xx :xxxxx::x::x: __ = ::xxxx--xxx:_ EXPENSES 2,850,463 1171 1,188.328 604,050 275.281 41.624 265,410 46.956 315.530 30,394 82,890 41.6891 21.191% 9.657% 1.4601 9.3111 1.6471 11.0691 1.066% 2.9081 ADMIN GENERAL ------------- 920 ADMIN GEN SAL 457.049 117 190.539 96.855 44.139 6.674 42,556 7.529 50.593 4,873 13.291 921 OFFICE SUPPLIES 118,195 117 49,274 25,047 11,415 1,726 11.005 1.,947 13,084 1,260 3,437 921 OUTSIDE SERV 48.267 117 20.122 10,228 4.661 705 4,494 795 5,343 515 1,404 924 FROP INS 17.123 107 6.422 4.281 1.303 363 1.655 468 1.685 171 775 925 INJ 6 DAMAGE 177.076 117 73.821 37.525 17,101 2,586 16.488 2.917 19,601 1.880 5.149 926 EMPLOYEE BNFT 592,675 117 247,060 125.596 57.237 8.655 55.105 9.763 65,606 6.320 17.235 ?28 REG COMM EXF 65.086 108 28,583 9.771 5.271 1.487 8.002 2.028 8.400 1001 1.542 929 DUP CHGS -5,320 117 -2.118 -1.127 -514 -78 -495 -88 -589 -57 -155 930 MISC GEN 199,249 117 03,065 42.223 19,242 2.910 18,552 3,282 22.056 2.125 5.794 . 932 MAINT GEN PLT 108,814 106 40,524 27.944 8.351 2,260 10.222 2.928 10,441 1,070 5,073 Total ---------- ------------- ------------- -------____--:=:--x=------ ------------- ------------- ---------- ADMIN GENERAL 1,778,214 1181 737,213 3771,342 168,207 27.287 167.665 31.570 196,220 19,166 53,544 41.458% 21.220% 9.459% 1.535% 9.4297. 1.775% 11.035% 1.070X 3.0111 SUBTOTAL EXPENSES 4.618,677 1191 1.925,541 981.392 443,488 68,911 433,074 78.526 511.750 49,560 136,434 41.6001 21.202% 9.581% 1.409% 9.3567. 1.6971 11.056X 1.0711 2.948X PURCHASED POWER IV (A C-) 1vno --------------- to = N FACILITY CHG 19.904 3 13.364 2,729 1.855 072 4,749 1,017 4.554 454 311 CD CD DEMAND CHG 4.599,912 3 2,055.636 419,832 285.324 134.100 730,566 156.426 700.452 69,774 47.802 ^� RATCHET DEMAND 775.464 2 300.216 475.240 0 0 0 0 0 0 0 0 m Subtotal------------- ------------- ------------- ------------- ------------- --------- Demand PF 5,40S.280 1201 2.369,216 897,809 287.179 134.972 735.315 157.443 705,006 70,228 48,113 ca 43,832% 16,6101 5.313% 2.497% 13.604X 2.913X 13.043X 1.299% 0.890% o ENERGY 1,184,695 4 558,053 134.503 82.329 23,150 151,975 47,446 139`510 22,702 26.027 FUEL & ADJSTMTS 6.796.292 4 3,201.407 771.610 472.302 132.806 871,842 272.185 794.595 130.237 149,308 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ----------•-- ------------- ------------- ------------- TOTAL ENERGY 7.980.987 1211 3,759.460 906.113 554,631 155,956 1,023,617 319.631 933.105 152,940 175,334 47.105% 11.353% 6.949% 1.954% 12.828% 4.005% 11.692% 1.9161 7.1971 South Plains Electric C000erative, Inc. Test Year Ended Seoteaber 30, 1991 Present Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH & CH LG LG POWER Gins Oilfield Sec Oilfield Pri Lighting -------------------------------7 ------------------------------------------------------------------------------------------------------------------------- Total_____________ _--_____=_=__--_=_________ _-_-____=__-_ ___-__-____-- _______--_-_- _____-_____=_ ______-_____- _--_-_______- =_-__-_-_-__- PURCHASED POWER 13.386.267 1221 6428,676 1,803.923 841,810 290,920 1.759,132 477,073 1,638411 223.167 223.447 45.7831 13.476% 6.289% 2.173% 13.141% 3.564% 12.237% 1.667% 1.669% DEPRECIATION 403.5 TRANSMISSION 403.6 DISTRIBUTION 403.7 GENERAL Total DEPRECIATION TAKES 408.1 PROPERTY 408.214 PAYROLL TAX 440.7 FRANCHISE Total TAKES OTHER DEDUCTIONS INTEREST CUST REPS OTHER DEDUCTIONS Total OTHER DEDUCTIONS TOTAL EXPENSES 58.425 101 1,573.620 104 152.137 106 1,784.182 1231 322.012 107 239,844 119 59.427 108 621.283 1241 12.769 108 46,485 119 61.254 1251 20.401.663 1261 25,825 4,598 3,480 1,825 9.672 2,230 9.346 811 638 586.041 404.109 120.774 32.688 147.826 42.342 151.009 15,468 73.363 56,658 39,069 11.676 3.160 14492 4.094 14.600 1.495 7.093 669.524 447.776 135.931 37.673 171.790 48.666 174.955 17.774 81.094 37.4701 25.097% 7.6191 2.112% 9.6281 2.720% 9,806% 0.9967. 4.5451 120.778 80.505 24.503 6.818 31.130 8.803 31.688 3.215 14.574 99,776 50,853 22.980 3,571 22,441 4.069 26.517 2,568 7,070 26.098 8.009 4.813 1.358 7.307 1.852 7.670 915 1.408 246,651 139,366 52.296 11,746 60,877 14,723 65.875 6,698 23,051 39.7001 22,432% 8.4171 1.891% 9.799% 2.3701 10.6031 1.0781 3.710% 5.608 1,721 1,034 292 1,570 398 1.648 197 303 20.170 10.280 4.645 722 4.536 823 5.361 519 1.429 25,777 12.001 5,680 1.014 6.106 1.220 7,009 716 1.732 42.083% 19.5921 9.272% 1.655% 9.9691 1.992% 11.4427. 1.1691 2,8277 -ovx� 8.995.169 3.384,458 1.479.204 410,273 2.430,979 620,209 2.397.699 297.915 465.75E Qc 43.918% 16.524% 7.2221 2.0031 11.869% 3.028t 11.707% 1.455% 2.2741 C ocn -h rn w� D South Plains Electric Cooperative. Inc. Test Year Ended September 30. 1992 Proposed Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oilfield Sec Oilfield Pri Liohtino ------------- ------ ------------- ------------------------------------------------------------------------------------------------------------------------- TRANSMISSION EXP 571 MAINT TRANS LINE 2.205 101 975 174 111 69 365 84 353 31 24 Total =__===___==__ Z=Z=Z=ZZZZZZ=------------- ------------=Z=ZxZZZZ==ZZ TRANSMISSION EXP 2.205 1111 975 174 131 69 365 84 353 31 24 44.202% 7.870% 5.957% 3.124% 16.555% 3.817% 15.996% 1.3871 1.093% DIST OPERATIONS --------------- 580 SUPV 6 ENGR 105.846 104 40,508 28.209 9.431 2.282 10,319 2,956 10,541 1,080 5.121 582 STATION EXP 27,233 1 12,037 2,143 1.622 951 4,508 1.039 4.356 378 296 583 OH LINE EXP 263.841 102 92.329 73.663 18.694 4.662 27,585 5.803 34.068 2.278 4.560 584 UG LINE EXP 557 10 153 209 56 22 70 28 11 8 0 586 METER EXP 321.018 13 126.168 62,240 18.715 2.557 11.661 1,944 86460 11473 0 587 CONS 1NST EXP 6.066 14 0 0 0 0 0 0 0 0 6.066 588 MISC DIST EXP 121.753 104 45,343 31,266 9,344 2.529 11,437 3,276 11.684 1.197 5,676 Total------------- ==_---------- ------------- m=====z===ZZx DIST OPERATIONS 850,314 1121 316,938 197,731 56.863 13.103 65.500 15.046 147,020 16.313 21.721 37.2731. 23.25411. 6.6871 1.541% 7.7121 1.7691 17.290% 1.918% 2,554% DIST MAINTENANCE ---------------- 590 SUPV 6 ENGR 69,182 104 25.764 17.766 5.310 1.437 6,499 1,862 6,639 680 3,225 592 MAINT SIN EOPT 194.779 1 86096 15.329 11.603 6.084 32,245 7.434 31.157 2,703 2.12E 593 MAINT OH LINES 308,163 107 107:039 66.038 21.034 5,679 32.218 6.778 39.791 2.660 5.326 514 MAINT UG LINES 164.576 10 45.256 61,716 16.45E 6,583 20,572 0.229 3.292 2,469 0 595 MAINT TRNSF 165.301 11 91.995 44.363 16.779 616 2.810 2,571 6.265 0 0 596 MAINT ST LT SYST 5.174 14 •> 0 0 0 0 0 0 0 5.174 597 MAINT METERS 77,542 13 20,511 14.065 4.229 578 2.635 439 19.515 2.570 0 598 MAINT MISC DIST 35,449 104 13.202 9.103 2321 736 3.330 954 3,402 348 1.653 Total =:-:-_'-'-=_= - - - - ------------- ----------- -----------:_ --------- ____________= -----------== =----=__=:::: ------------- ------------- DIST MAINTENANCE 1.015.166 1131 399.565 248,380 78.934 21,714 100.310 28.266 110.060 11.430 17.506 -- 39.261% 24.4611 7.1151 2.139% 9.081% 2.7841 10.842% 1.1261 1.724% -0 to c- c) 0 C: E(PENSES 1.867,685 1141 716,476 446.284 135,928 34,886 166,255 43,396 257.433 27,773 39.251 �-• c 38.362% 23.895% 7,278% 1.068% 8.9021 2.3241 13.7041 1.4871 2,1027. o m CONS ACCTS --' ---------- w N 902 METER READ EXP 205,808 6 86.900 29,331 44,099 11010 15,355 256 9.666 203 18,90E c 905 CUST RECORDS 582,960 9 291,911 98,52E 74.068 3,393 61.897 688 32.469 950 19.055 904 UNCOLL ACCTS 72.000 15 32,261 9.416 5.480 1,566 9,073 2.466 8.839 1.171 1.729 Total =_==_:____:__ _____________ _____:___=___------=_--_-- CONS ACCTS 860,768 1151 411.072 137.276 123,647 5.970 86,325 3.410 50.973 2,404 39.692 47.756% 15.9481 14.365% 0.694% 10.029% 0.396% 5.922% 0.2191 4.611% South Plains Electric C000eratire. Inc. Test Year Ended Seotewber 30. 1992 Proposed Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH & CH LG LG POWER 6ins Oilfield Set Oilfield Fri lighting -------------------- ------------- ------------------------------------------------------------------------------------------------------------------------- CUST SERV EIP ------------- 909 CUST ASSIST 13.513 9 6,766 2,184 1,717 79 1,435 16 753 22 442 909 ADVERT & FROM 9,343 9 4.679 1.579 1,107 54 992 11 520 15 305 910 MISC CUST ASSIST 34.233 9 17.142 51786 4.349 199 3.635 40 1,907 56 1.119 912 DEMO & SELL 64.921 9 32,509 10.973 0.249 379 6.893 77 3.616 106 2,122 Total zzszzszzssxxa --s-zxz--sass sxaszxszzzaaa zsszzszszz:za xzacazasxzzzs szxxxszzasaxs zxzasaszzsxx: axszxsazzxzs: -ass-zzzaasas sxasaxsaxsxss CUST SERV EIP 122.010 1161 61.095 20.621 15.502 710 12.955 144 6,796 199 3,988 50.074% 16.901% 12.706% 0.582% 10.610% 0.118% 5.5701 0.163% 3.2691 SUBTOTAL axazaszzszazz xzxzzxzzzxzzz zxazxxxszsazz zzzzxzzzazzxz zzaszxzsxxzxx szazzzzzzszzs zzsxzssszzzaa xzzzzzxzxzxsz asmazxzssaaas szaassazxzxsa EXPENSES 2.850,463 1171 1.188.645 604,191 275.079 41,566 265,535 46,950 315,201 30,376 82,931 41.700% 21.196% 9.6501 1.45B1 9.3151 1.647% 11.0581 1.066% 2.909% ADMIN GENERAL ------------- 920 ADMIN GEN SAL 457.049 117 190.590 96.876 44.106 6,665 42,576 7,529 50,540 4,870 13,297 921 OFFICE SUPPLIES 118.195 117 49.287 25.052 11,406 1.724 11,010 1.947 13.070 1.260 3.439 923 OUTSIDE SERV 48.267 117 20.127 10.231 4.658 704 4.496 795 5.337 514 1,404 924 PROP INS 17,123 107 6.422 4.281 1,303 363 1,655 468 1.685 171 775 925 INJ & DAMAGE 177,076 117 73,841 37.533 17,080 2,582 16,496 2,917 19.581 1.887 5,152 926 EMPLOYEE BNFT 592,675 117 247,146 125.623 57,195 8,642 55.211 9,762 65.537 6,316 17,243 928 REG COMM EIP 65,006 108 28.942 8.098 51042 1,423 8,143 2,030 9,036 985 1,597 929 DUP CHGS -5,320 117 -2,210 -1,128 -513 -76 -496 -89 -588 -57 -155 930 MISC GEN 199,249 117 83.067 42.233 19,228 2,905 18.561 3,282 22,033 2,123 5,797 932 MAINT GEN PLT 100,814 106 40.524 27.944 8,351 2,260 10..222 2.928 10,442 1,070 5,073 Total zaxasazazszsx z-x-zzczzzazs zszzzsszzzzzz zszzzzszzxszz z-z =z-ssxzzz zazzzzzzzzzas asxzxzsxxszza xxazzzzxzsazx xzzxzsaaasxxs aazzzzzzaxzas ADMIN GENERAL 1,77B,214 1181 737,748 377,542 167,865 27.190 167,875 31,568 195,673 19,139 53,612 41.4881 21.2321 9.440% 1.5291 9.4411 1.775% 11.0041 1.076% 3.0151 SUBTOTAL zzzsxszazxzzz szaszzzsxszzx ssssxxszxsasz assxsxzsxzzss szzaszzssxasz zzzzszzzzzaxs ssxzxzzzszzzz ssszaxzzzzzsz zzzzzazaaxssa zazsssszzxzsz EXPENSES 4,628.677 1191 1,916,393 181.724 442.942 68.756 433.410 78.518 510,874 49,515 136,544 41.619% 21.210% 9.5701 1.4051 ' 9.364% 1.6961 11.037% 1.070% 2.950% PURCHASED POWER -- ------------ FACILITY CHG 29.904 3 13.364 2,129 1.055 872 4,749 1.017 4,554 454 311 DEMAND CHG 4.599,912 3 2,055.636 419.832 205.324 134,100 730,566 156.426 700.452 69.774 47.802 RATCHET DEMAND 775,464 2 300,216 475,248 0 0 0 0 0 0 0 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- Demand PP 5,405,280 120t 2,3691.216 897.609 287.179 134,972 735,315 157,443 705.006 70,228 48,113 43.632% 16.610% 5.313% 2.497% 13.604% 2.9131 13.0431 1.299% 0.990% ENERGY 1.184.695 4 558,053 134,503 $2,329 231,150 151,975 47,446 138.510 22,702. 26,027 FUEL i ADJSTMTS 6,196.292 4 3,201,407 .771.610 472.302 132.806 871.842 272,185 794,595 130.237 149.308 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- ------------- TOTAL ENERGY 7,980.987 1211 3.759,460 906,113 554,631 155,956 1,023,817 319,631 933,105 152.940 175.334 -p (n n cu0O to s (n rD rD a N C J O rD -fi -n N 0 .-,�-I ,--I p-.--I �I ��1 7-1 �-! �-1 `mil �l --1 South Plains Electric Cooperative, Inc. test Year Ended September 30, 1992 Proposed Rates COST OF SERVICE ALLOCATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oilfield Sec Oilfield Fri Lighting -------------------- ------------- ------------------------------------------------------------------------------------------------------------------------- total z=ZzZ=x==z=== ===_======_=_---------- ----------------===___=_===_ _____________ =z===Z=z==Z= ---_-_-_---_= PURCHASED POWER 13.386,267 122t 6,128,676 1,903,923 641.810 290.928 1,759,132 477,073 1,639.111 223.167 223.44? 45.183i; 13,476% 6.2891 2.173% 13,141% 3.5641 12.237% 1.667% 1.669% DEPRECIATION 403.5 TRANSMISSION 403.6 DISTRIBUTION 403.7 GENERAL Total DEPRECIATION TAXES 408.1 PROPERTY 408,214 PAYROLL TAX 408.7 FRANCHISE Total TAXES OTHER DEDUCTIONS INTEREST CUST DEPS OTHER DEDUCTIONS Total OTHER DEDUCTIONS TOTAL EXPENSES 58,425 101 11,573.620 104 152.137 106 1.784.182 123t 322,012 107 239,844 119 59.427 108 621,283 1241 12,169 100 48.485 119 61,254 1251 20.481.663 1261 25.625 4,598 31480 1,825 9,672 2.230 9.346 811 636 586,041 404,109 120,774 32.688 147.826 42,342 151.1009 15,468 73.363 56.658 39.069 11,676 3.160 14,292 4,094 14,600 1,495 7.091 668.524 447,776 135.931 37.673 171.790 48.666 174.955 17.774 81,094 37.470% 25.097% 7.619% 2.112% 9.628% 2.128% 9.9061 0.996% 4,545% 120.778 80.505 24,503 6,619 31.130 8.803 31,688 3,215 14.574 99,820 50.870 22,952 3,563 22.458 4,069 26,472 21.566 7,075 26,426 8,125 4.604 1,299 1,435 1453 7437 899 1,449 247,023 139.500 52.059 11,679 61.023 14.725 65.497 6,680 23.098 39,760% 22.453% 8.3791 1.880% 9.6221 2.170% 10.542% 1.075% 3.718% 5.618 1,746 989 279 1.598 396 1,577 193 311 201179 10.283 4,640 120 4,540 822 51351 $19 1,430 25.957 12.029 5,629 999 6.138 1,221 6.926 712 1,742 42,213% 19.6381 9.190% 1.631% 10.020% 1.9937. 11.310% 1.162% 2,8437. __=---_-_-_-_ ---___-_---__ ==-_==---_=== =_=_===__---= 8,996,473 3.384,951 1.479,371 410,037 2.431.492 620.203 2,396,364 297,848 465,924 ,. 43.925% 16.5277. 7.218% 2.0021 11.8721 3,0287. 11.100% 1.454% 2.2751° . a N r7 Sb n O fm 2 Cn - rD m v w c r om --h wi N r F SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PURCHASED POWER COST YEAR ENDED SEPTEMBER 30, 1992 COS Schedule G-1.0 JAN 92 FEB MAR APR MAY JUN JULY MINIMUM KW 69,930 69,930 69,930 69,930 69,930 69,930 69,930 r ACTUAL KW 58,880 52,545 49,026 52,851 57,557 60,563 78,876 RATCHET DEMAND $66,300 $104,310 $125,424 $102,474 $74,238 $56,082 $0 ACTUAL DEMAND 353,280 315,270 294,156 317,106 345,342 363,498 $473,256 fTOTAL DEMAND $419,580 $419,580 $419,580 $419,580 $419,580 $419,580 $473,256 KWH PURCHASED 30,644,400 23,674,893 21,734,421 25,516,000 26,397.652 23,612,800 33,444,200 ENERGY COST $104,191 $80,495 $73,897 $86,754 $89,752 $80,284 $113,710 FACILITY CHG 2,492 2,492 2,492 2,492 2,492 2,492 $2,492 " FUEL COST ADJ/KWH 0.018807 0.017999 0.017479 0.016342 0.017753 .0.018163 0.018161 FUEL COST ADJ 576,329 426,124 379,896 416,983 468,638 428,879 $607.380 r ADJUSTMENTS 30,793 (28,132) (31,530) 13,562 20,311 (9,952) ($2,999) SUBTOTAL $713,805 $480,979 $424,755 $519,791 $581,193 $501,703 $720,583 TOTAL SPS BILLING $1,133,385 $900,559 $844,335 $939,371 $1,000,773 $921283 $1,193,839 SERVICE CHARGES 30,086 11,311 17,566 22,548 46,282 35,616 41,419 TOTAL POWER BILL $1,163,471 $911,870 $861,901 $961,919 $1,047,055 $956,899 $1,235,258 f R AUG SEP 92 OCT 91 NOV DEC 91 TOTALS MINIMUM KW 69,930 62,836 69,930 69,930 69,930 832,066 7 ACTUAL KW 104,096 83,554 52.649 56,251 59,784 766,652 RATCHET DEMAND $0 $0 $103,686 $82,074 $60,876 $775,464 ACTUAL DEMAND 624,576 501,324 315,894 337,506 358,704 $4,599,912 TOTAL DEMAND $624,576 $501,324 $419,580 $419,580 $419,580 $5.375,376 KWH PURCHASED 50,586,400 32,232,400 22,028.400 24,085,000 34,483,000 348,439,566 ENERGY COST $171,994 $109,590 $74,897 $81.889 $117.242 $1,184,695 FACILITY CHG 2,492 2,492 2,492 2,492 2,492 $29,904 t FUEL COST ADJ/KWH 0.018625 0.018834 0.017539 0.018748 0.019198 FUEL COST ADJ 942,172 607.065 386,356 451,546 662,005 $6,353,373 ADJUSTMENTS (9,833) (9,004) 32,620 46,788 32,122 $84,746 SUBTOTAL $1,106.825 $710,143 $496,365 $582,715 $813,661 $7,652,718 4 TOTALSPS BILLING $1,731.401 $1,211,467 $915,945 $1,002,295 $1,233,441 $13,028,094 SERVICE CHARGES 65,215 38,315 13,890 15,929 19,996 $358,173 TOTAL POWER BILL $1,796,616 $1,249,782 $929,835 $1,018,224 $1,253,437 $13,386,267 r- RATE: ALL MOS JAN-SEP OCT-DEC DEMAND COST/KW: $6.00 ENERGYCOST/KWH: $0.0034 FACILITY CHARGE/MONTH: $2,314.00 $2,492.00 7 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates SUMMARY OF COMPONENTS OF EXPENSES SYSTEM TOTALS ------------- RESIDENTIAL -------------------------- IRRIGATION GEN SERVICE ------------- SCH & CH LG ------------- LG POWER -------------------------- Gins Oilfield Sec ------------- Oilfield Fri ------------- - Average Consumers 31,304 16,129 5.444 1.637 25 114 19 897 21 kWh Sold 317.703.216 149.371.203 36.001.043 22,037.006 6.196.620 40.679.006 12.699.580 37.074.314- 6.677.091 kW1 426.157 75.874 57.433 30.117 159.605 .36,799 154.220 13.377 kW2 342.606 69.972 47.554 22.350 121,761 26,071 - 116,742 11,629 Customer Component 3.015,251 1,500,728 960.874 370.821 39.102 255,923 40.918 368.559 40.258 Monthly Cost Per Cons 10.16 7.75 14.71 18.88 130.34 187.08 179.47 34.24 159.75 Cost Per kW1 3.52 12.66 6.46 1.30 1.60 1.11 2.39 3.01 Cost Per kW2 4.38 13.73 7.80 1.75 2.10 1.57 3.16 3.46 Eneror Component 9.241.397 3.674.358 940,515 575.476 161.872 1.655.992 328.122 966.506 157.092 Average Cost Per kWh 0.025941 0.025938 0.026124 0.026114 0.026123 0.025959 0.025837 0.026069 0.023525 Demand Component 9.779.944 4.128,578 1.821,044 635,934 238.030 1.250.356 288.256 1.196.240 114.121 Cost Per kW1 9.69 24.00 11.07 7.90 7.83 1.93 1.76 8.53 Cost Per kW2 12.05 26.03 13.37 10.65 10.27 11.06 10.25 9.81 Demand Purchased Power 5.405.280 2,369,216 897,009 287.179 134,972 735.315 157,443 l05.006 70,229 Cost Per kW1 5.56 11.83 5.00 4.48 4.61 4.28 4.57 5.25 Cost Per kW2 6.92 12.03 6.04 6.04 6.04 6.04 6.04 6.04 Demand System Component 4,374.664 1,159,362 923,235 348,756 103.050 515,041 130.813 491.234 43,693 Cost Per kWl 4.13 ' 12.17 6.07 3.42 3.23 3.55 3.19 3.28 Cost Per kW2 5.14 13.19 1.33 4.61 4.23 5.02 4.21 3.77 Demand & Eneror Component 18.021,341 8.002.935 2,761,560 1,211,411 399.902 2,306.348 616.379 2.162.746 271.203 Average Cost Per kWh 0.056724 0.053577 0.076706 0.054972 0.064536 0.056696 0.048535 0.058335 0.040617 Total Exoenses 21.836.592 9.503.664 3,722.433 1,582,232 439,004 2.562,271 657.297 .2.531.305 311.460 Average Cost Per kWh 0.068733 0.063624 0.103396 0.071799 0.070046 0.062988 0.051757 0.068277 0.046646 kW1=964111 kW2=766652 --I ---I ---I '---] 7-1 7--1 -1 7-1 ' v-1 South Plains Electric Cooperative. Inc. Test Year Ended Seotee6er 30. 1992 Present Rates COMPONENTS OF EXPENSES ACCOUNTS -------------------- TOTAL DOLLARS A.F. ------------- RESIDENTIAL IRR16ATION GEN SERVICE SCH # CH LG L6 POWER Gins Oilfield Sec Oilfield Pri ------------- Lighting DEMAND COMPONENT ------------- ---- -------------------------- -------------------------- ------------- ------------- ------------- ---------------- NONCOIN DEMAND 2,442.930 1 1.079,819 192.254 145,527 76,312 404,416 93,243 390.771 33.895 26.694 RATCHET DEMAND 775.464 2 300.216 475.248 0 0 0 0 0 0 0 COIN DEMAND 4.629.816 3 2.069.000 422.561 287.179 134.972 735.315 157.443 705.006 70.228 48.113 CONSUMER #2 WTD 50% 170.182 6 71.857 24.254 36.465 835 12.697 212 7.993 234 15.635 CONSUMER 03 1 PH 60% 183.771 7 155.243 2.607 8.979 0 0 0 0 0 16,942 CONSUMER 14 3 PH 601 499.357 8 3.409 352,784 48,139 1.705 19,432 1,295 61.161 1.432 0 ACCT 366!367 50% 555.479 10 152,757 208.304 55,548 22,219 69.435 27.774 11.110 9.332 0 ACCT 368 TRANSFR 60% 532,945 11 296.277 143.032 54.098 1.987 9.061 8.289 20.200 0 0 TOTAL------------- ------------- -------------------------- -------------------------- ------------- -------------------------- --------- DEMAIID COMPONENT 9,779,944 4,128,579 1,821.044 635,934 239.030 1.250,356 288.256 1,196,240 114.121 107.384 42.215% 18.620% 6.502% 2.4341 12.795% 2.947% 12.232Z 1.167% 1.096% CUSTOMER COMPONENT ------------------ CONSUMER 12 WTD 50% 170,182 6 71,957 24,254 36,465 835 12,697 - 212 7.993 234 15,635 CONSUMER #3 1 PH 40% 122,514 7 103,495 1,739 5,986 0 0 0 0 0 11.295 CONSUMER 14 3 PH 40Z 326.238 8 2.273 235.190 32.092 1,136 12.955 864 40.774 955 0 CONSUMER #5 CONS A/C 1.165.876 9 583,901 197.049 148.131 6.797 123,799 1.375 64.935 1.900 39.109 ACCT 366/367 50% 555.479 10 152.757 208,304 55,548 22,219 69,435 27.774 11.110 8.332 0 ACCT 368 TRANSFR 40% 355.297 11 197.510 95,355 36,066 1,325 6,041 5,526 13.467 0 0 ACCT 369 SERVICES 132,654 12 69.113 41.167 9,078 315 1.437 239 11.305 0 0 - ACCT 370 METERS 913.381 13 319.915 157,817 47,455 6,484 29.569 4,928 218,976 28.837 0 ACCT 371 INST CONS P 173,031 14 0 0 0 0 0 0 0 0 173,031 TOTAL------------- ------------- -------------------------- -------------------------- ------------- -------------------------- ------------- CUSTOMER COMPONENT 3,815.251 1,500.728 960,974 370,821 39,102 255,923 40.918 368.559 40.259 23B.069 39.335% 25.195% 9.719% 1.025% 6.709% 1.072% 9.660% 1.055% 6.240% ENERGY COMPONENT ---------------- to C') 0 O ENERGY FACTOR 7,990.987 4 3.759.460 906,113 554.631 155,956 1.023.817 319,631 933,105 152,940 175,334 BASE REVENUE 291.531 15 129.344 37.595 23.014 6.577 36.229 10.010 37,117 4.814 6.831 c - PCRF REVENUE -31.121 16 -14,446 -3.192 -2.168 -661 -4.054 -1.519 -3.716 -672 -693 TOTAL ------------- ------------- -------------------------- -------------------------- ------------- -------------------------- ------------- x ENERGY COMPONENT 9,241.397 3,974,358 940,515 575,476 161,972 1,055,992 328.122 966,506 157,082 181,473 ry 47.011% 11.412% 6.983% 1.9641 12.813% 3.981% 11.7271 1.906% 2.2021 c TOTAL z=z===zzzz=zz ==---___==___ __=__________ ===_-_____=== _____________ __________=__ _===-=___-___ ====______=__ __=_=__=_____ ==--__-____-_ EXPENSES 21,836,592 9,503,664 3,722.433 1,582,232 439.004 2,562,271 657,297 2.531.305 311.460 526,927 43.5221 17.047% 7.246% 2.010% 11.734% 3.010% 11.592% 1.426% 2.4131 7-7 South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates COMPONENTS OF PLANT ACCOUNTS TOTAL DOLLARS ------------- A.F. ----------------- RESIDENTIAL IRRIGATION GEN SERVICE ------------- SCH 6 CH LG ------------- LG POWER ------------- Gins Oilfield Sec Oilfield Pri -------------------------- Liohtina ------------- -------------------- DEMAND COMPONENT ------------- ------------- ---------------- NONCOIN DEMAND 21.787,704 1 9.630.556 1.714.647 1.297.906 690.602 3.606.851 931.606 3.495,159 302.302 239.076 CONSUMER 13 1 PH 601 1.590.010 1 1.334.734 22.413 77.200 0 0 0 0 0 145.664 CONSUMER 14 3 PH 60% 4.207.359 8 29,311 3.033.144 413,077 14.656 167.075 11.139 525.847 12.311 0 ACCT 366/367 50% 5.774.990 10 1.590.122 2.165.621 577,499 231,000 721,874 288,749 115.500 86.625 0 ACCT 368 TRANSFR 60% 5.085,606 11 2.827,214 1.364,875 516,232 19,961 86,464 79,099 192.762 0 0 TOTAL------------- ------------- -------------------------- -------------------------- ------------- -------------------------- ------------- DEMAND COMPONENT 38.435.670 15,409,937 8.300.101 2.982.714 945.219 4,592.264 1.210,593 4,319,266 401,237 383,740 40.093% 21.596% 7.500% 2.459% 11.9221 3.150% 11.238t 1.044R 0.998% CUSTOMER COMPONENT ------------------ CONSUMER #3 1 PH 407 1.053.340 7 889,822 14,942 51,467 0 0 0 0 0 97.109 CONSUMER 14 3 PH 40% 2.804,906 8 190541 2.022,096 275.918 9,770 111,383 7,426 350..564 9.201 0 ACCT 366/367 50% 5.774.990 10 1.588.122 2.165.621 577.499 231.000 121.974 298.749 115.500 86.625 0 ACCT 368 TRANSFR 40% 3.390.404 11 1.094.009 909.917 344,155 12,641 57,643 52.732 128.508 0 0 ACCT 369 SERVICES 1,828.642 12 952,732 567.484 125.137 4,343 19,806 3,301 155.939 0 0 ACCT 370 METERS 2,249'528 13 8939727 435.952 131.1090 17,912 91.681 13,613 604,694 79.658 0 ACCT 371 INST CONS P 2.128,996 14 0 0 0 0 0 0 0 0 2.128.996 TOTAL------------- ------- --- -------------------------- -------------------------- ------------- -------------------------- ------------- CUSTOMER COMPONENT 19.229,806 6,210,753 6,116,012 1,505,265 275,667 992,386 365.022 1.355.30b 174.490 2,226.105 32.339% 31.805% 7.9291 1.4347. 5,161% 1.902% 7.049% 0.907% 11.576% TOTAL zz=mm=====2=2 PLANT 57.665.476 21.628.690 14.416.713 4.307,900 1.220.886 5.574.650 1.576.414 5.674.571 575.727 2.609.945 37.507% 25.001% 7.609% 2.117% 9.667% 2.7341 9.841% 0.998% 4.526% to C) 0 O = (A rD a C fD 2 W O South Plains Electric Cooperative. Inc. Test Year Ended September 30, 1992 Present Rates COMPONENTS OF RATE BASE ACCOUNTS TOTAL DOLLARS A.F. RESIDENTIAL IRRIGATION GEN SERVICE SCH 6 CH LG LG POWER Gins Oilfield Sec Oilfield Fri Lighting ------------- -----------=-------- DEMAND COMPONENT ------------- ---- -------------------------- -------------------------- -------------------------- -------------------------- ---------------- NONCOIN DEMAND 14,018.943 1 6,196.624 1,103,262 835,116 437,922 2,320.770 535,093 2.242,468 194.511 153,186 RATCHET DEMAND 109.599 2 42.431 67.169 0 0 0 0 0 0 ` 0 COIN DEMAND 654.349 3 292.420 59,722 40.588 19,076 103,925 22,252 99,641 9.926 6.900 CONSUMER 12 WTD 50% 6.232 6 2.632 B88 1.335 31 465 8 293 9 473 CONSUMER 13 1 PH 60% 1.030.684 1 810.683 14.621 50,360 0 0 0 0 4 95.020 CONSUMER 44 3 PH 60% 2.744.575 8 19.121 1,978,602 269,983 9,560 108.989 7,266 343.024 6.031 0 ACCT 3661367 501 3.762.927 10 1.034.805 1.411.098 376.293 150.517 470.366 198.146 75,259 56,444 0 ACCT 368 TRANSFR 60% 3.315.334 11 1.843.076 889.770 336.534 12.361 56.366 51.565 125.662 0 0 TOTAL------------- -------------------------- -------------------------- DEMAND COMPONENT 25,642.644 10.301.790 5.525.131 11910,210 629,468 3.060.979 804.320 2.806.347 268,920 255.579 40.174% 21.547% 7,449% 2.455% 11.937% 3.137% 11.2561 1.049% 0.997% CUSTOMER COMPONENT ------------------ CONSUMER 12 WTD 501 6.232 6 2.632 888 1,335 31 465 8 293 9 573 CONSUMER 13 1 PH 40% 697,122 7 580,455 9,747 33,573 0 0 0 0 0 63,347 CONSUMER 14 3 PH 40% 1,829.717 8 12.747 1.319.068 179.989 6.374 72.658 4.844 229.683 5.354 0 CONSUMER 15 CONS A/C 42.697 9 21,380 7,216 5,425 249 4,533 50 2.378 70 1,396 ACCT 366/367 501 3.762.927 10 1,034,805 1.411.098 376.293 150,517 470.366 188,146 75.259 - 56.444 0 ACCT 368 TRANSFR 40% 2.210.223 11 1.228.717 593.100 224,356 8,241 37.578 34.377 83.775 0 0 ACCT 369 SERVICES 1,199,942 12 619,966 369,276 81.430 2,816 12.800 2.148 101,408 0 0 ACCT 370 METERS 1.487.008 13 584,431 208,306 86.693 11.646 54,018 9.003 400,032 52,680 0 ACCT 371 INST CONS F 1.386.070 14 0 0 0 0 0 0 0 0 1,306.070 TOTAL------------- -------------------------- -------------------------- -------------------------- -------------------------- ------------- CUSTOMER COMPONENT 12,601,938 4,085433 3,998.779 999,094 180,083 652.506 238.576 891,827 114.556 1,451,385 32,417% 31.1311 7.849% 1.429% 5,1781 1.8931 1.0111 0.909% 11.5171 - ENERGY COMPONENT c ---------------- s v c� ENERGY FACTOR 262,399 4 123,599 29,790 18,234 5,127 33,660 101500 30.677 9.028 5.764� BASE REVENUE -197.153 15 -87,471 -25.424 -15.564 -4,448 -24.500 -6.769 -25.101 -3,256 -4.620 PCRF REVENUE 36,365 16 16.880 3,730 2.534 773 4,737 1,774 4.342 795 810 = TOTAL------------- -------------------------- -------------------------- -------------------------- -------------------------- ------------- I ENERGY COMPONENT 101.600 53.008 9,096 5.205 1,452 13.996 5.513 9,918 2.558 .�a 1.954 0 52.173% 7.969% 5.1231 1.429% 13.6791 5.426% 9.762% 2.518% 1.923% TOTAL =____==______ ==__=_=_=_=-- -- ---------- --==_---_==== _______-____- _----____---_--=--=---===_ __--_-_-____= ====-___===-_ _-===__=--=__ RATE BASE 38,346.182 14.439,931 9.532.006 2.904.509 811.002 3.727.282 1.048.409 3.788,092 386.033 1,708,918 37.657% 24.858% 7.574% 2.115% 9.720% 2.7341 9.8791 1.007% 4.4571 ---1 7-1 ----1 ,-'1 7-.1` --1 ---1 ---1 T--1 �1 T�1 r_� � � r ., -I 71 South Plains Electric C000erative. Inc. lest near Ended Seoteeber 30, 1992 Present Rates CLASSIFICATION - PLANT ACCOUNTS TOTAL DOLLARS A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE TRANSMISSION PLANT 350 LAND & RIGHTS 74.617 1 74.617 0 0 0 0 353 STATION EOPT 1.114.899 1 1.114399 0 0 0 0 355/356 POLE 4 COND 1.010.853 1 1.010.853 0 0 0 0 Total _____________ _zzz=zz___=z_ zzczzz==zz=cs __zzzzszzzzza TRANSMISSION PLANT 2.200.369 1011 2.200,369 0 0 0 0 100.000% 0.000% 0.000% 0.000% 0.0007. DISTRIBUTION PLANT ------------------ 360 LAND 112.054 1 112.054 0 0 0 0 362 STATION EOPT 5.046,723 1 5.046,723 0 0 0 0 364/365 1 PH 2.423.431 7 1.454,059 969.372 0 0 0 364/365 3 PH 6.453,277 8 3,871,966 2,581,311 0 0 0 364/365 BACKBONE 11,014,009 1 11,014.009 0 0 0 0 Subtotal------------- ------------- ------------- ------------- ------------- ------------- ACCT 364/365 19,890.717 102t 16.340.034 3.550.683 0 0 0 B2.149% 17,851% 0.000% 0.0001 0.0001 366/367 UG 10.629.263 10 5.314,632 5,314,632 0 0 0 368 REGS 6 CAPCTORS 1,653.128 1 1.853.128 0 0 0 0 368 TRANSFORMERS 7,800.338 11 4.680,203 3,120.135 0 0 0 Subtotal------------- ------------- ------------- ------------- ------------- ------------- TOTAL TRANSFORMERS 9.653.466 1031 6.533.331 3,120,135 0 0 0 67.679% 32.321% 0.000% 0.000% 0.000% 369 SERVICES 1,687,870 12 0 1.682,670 0 0 0 370 METERS 2.069.285 13 0 7.069.285 0 0 0 371 INST CONS PREM 1.959.781 14 0 1.959.281 0 0 0 Total------------- ---------____ --------- ---------- ---------____ ----z-=_z_z-= DISTRIBUIION PLANT 51,043,659 1041 33,346,773 17,696,886 0 0 0 65.3301 34.670% 0.000% 0.000% 0.000% SUBTOTAL =zr_=zz=z=r_z s=z=rrzzzzs ==cz==s==z=r z=zzzz=zest-_ -_-_----_ =zz ssz as_ ------ PLANT 53.244.028 1051 35.547.142 17,696,886 0 0 0 66.7631 33.237% 0.000% 0.0001 0.000% GENERAL PLANT ------------- TOTAL GENERAL PLANT 4.411.448. 104 2.888.528 1,532,920 0 0 0 Total zsszzzzzzzzzz =zz==zz==s==z zzzzzzzzzzzzz zzzzzzsamczzz ez=zzzzzazzzz zzzzz==z=z:a= GENERAL PLANT 4.421,448 IM 2.888.528 1.532.920 0 0 0 w 0 o Un ::- cn cD cD a rc o rD —a x 03 o' South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates CLASSIFICATION - PLANT ACCOUNTS TOTAL DOLLARS A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE TOTAL zzzzzzzzzzzzz ===__ _----- ===_====_==== ==zxzz=====zz PLANT 57.665.476 1074 38,435.670 19,229.806 0 0 0 66.653% 33.347% 0.000% 0.000% 0.000% TJNC� W 0 O (D (D CL N C d (D 2 00 1 O South Plains Electric Cooperative, Inc. Test Year Ended September 30. 1992 Present Rates CLASSIFICATION - REVENUES e ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE ENERGY REVENUE ---- -------------------------- ------------- ------------- ------------- -------------- BASE REVENUE 24.870.623 15 0 0 24.870.823 0 0 PCRF REVENUE -4.408,127 16 0 0 -4,488,127 0 0 - Total------------- ------------- ------------- ------------- -------------------------- ------------- ------------- ____=________ =___=______== ENERGY REVENUE 20.392,696 108t 0 0 20,382.696 0 0 0.000% 0.000% 100.000% 0.000% 0.000% OTHER REVENUE ------------- OTHER REVENUE 127.704 17 0 0 0 0 127.704 TotalZZZ=ZZZZ=Z=ZZ----------- ------------- ------------ ------=------ OTHER REVENUE 127.704 1091 0 0 0 0 127,704 0.000% 0.000X 0.000% 0.000% 100.000% TOTAL==-==----=-== ------------------------- ------------- ------------ REVENUES 20.510.400 110t 0 0 20.382.696 0 127.704 01000% 0.000r 99.377% 0.000% 0.623% -O (/) CQ S N (D (D a W C ._.. O (D -h 2 co 1 (Jl iz --I - South Plains Electric Cooperative, Inc. Test Year Ended September 30. 1992 Present Rates CLASSIFICATION - EXPENSES ACCOUNTS TOTAL DOLLARS A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE TRANSMISSION EXP ---------------- 571 MAINT TRANS LINE 2.205 101 2.205 0 0 0 0 Total _____________ =____====Cs== TRANSMISSION EXP 2.205 lilt 2.205 0 0 0 0 100.000% 0.000% 0.0001 0.000% 010001 DIST OPERATIONS --------------- 580 SUPV & ENGR 109,846 104 71,762 38.084 0 0 0 592 STATION EXP 27.233 1 27.233 0 0 0 0 583 ON LINE EXP 263.841 102 216.743 47,098 0 0 0 584 UG LINE EXP 557 10 279 279 0 0 0 596 METER. EXP 321.019 13 0 321.018 0 0 0 587 CONS INST EXP 6.066 14 0 6.066 0 0 0 598 "ISC DIST EXF 121.753 104 79.541 42.211 0 0 0 Total =-=_---_°____ ------=---=-- ------------- =--==-------- --==--------= ==----------- DIST OPERATIONS 950.314 1121 395,558 454.756 0 0 0 46.519% 53.491% 0.0007. 0.000% 01000% DIST MAINTENANCE ---------------- 590 SUPV & ENGR 69.182 104 45.197 23.995 0 0 0 592 MAINT STR EOPT 194.779 1 194,779 0 0 0 0 593 MAINT ON LINES 308.163 102 253.153 55,010 0 0 0 594 MAINT UG LINES 164.576 10 82.188 82.288 0 0 0 595 MAINT TRNSF 165,301 11 99.191 66,110 0 0 0 596 MAINT ST LT SYST 5,174 14 0 5.174 0 0 0 597 MAINT METERS 72,542 13 0 72.542 0 0 0 598 MAINT MISC DIST 35.449 104 13.159 12,290 0 0 0 Total _____________ _=_==_=_=____ __=_•______=_ _____=====p°= ___=________: :____:__g____ DIST MAINTENANCE 1.015.166 1131 697,756 317,410 0 0 0 66.733% 31,267% 0.000% 0.000% 0.000% SUBTOTAL _____________ ----_=___==:= ======aa----= =_____°______------------- ------------- EXPENSES 1.867.05 1141 1.095.519 772.166 0 0 0 58.656% 41.344% 0.000% 0.000% 0.000% a n o CONS ACCTS to S cn m m ---------- CL 902 METER READ EXP 205.808 6 102.904 102.904 0 0 0 903 OUST RECORDS 592.960 9 0 592.960 0 0 0 0 -h(D 904 UNCOLL ACCTS 72.000 15 0 0 72.000 0 0 Xb = Total ===s=======s= ______=====ss CONS ACCTS 860,769 .1151 102.904 695.864 72,000 0 0 0 11.955% 79.680% 8.365% 010001 01000% South Plains Electric Cooperative, Inc- - Testl Year Ended September 30, 1992 -_ = Present Rates CLASSIFICATION - EXPENSES 1 - s- ACCOUNTS. TOTAL DOLLARS A.F, DEMAND CUSTOMER ENERGY FUEL REVENUE COST SERV EXP ------------- 908 COST ASSIST 13,513 9 0 13.513 0 0 0 909 ADVERT 6 PROM 9,343 9 0 9,343 0 910 RISC COST ASSIST 34.233 9 0 34,233 0 0 . - 0 912 DEMO 6 SELL 64,921 9 0 64.921 0- 0 .' q Total sassaszzaxxxx x»-:-zsssasz aasasazzrssz zsasxsassszss ssasrssssaxz zzszzxa____xr .'... COST SERV EXP 122.010 1161 0 122.010 0 0 0 0.000E 100.000E 0,000X 0.000E 0.000% - SUBTOTAL azzzaszszzzse sxxzr_zsza_za saszsaaxxzzzs ssszxsxzassas ----aassssszs 'taaseasrzse: EXPENSES 2.950.463 1171 1,199.423 1.580.040 72,000 0 0 42.043% 55.431% 1.526X 0.000E 0.000E` ADMIN GENERAL , 920 ADMIN GEN SAL 451.049 117 192.158 253,341 11,545 0 0 921 OFFICE SUPPLIES - 118.195 117 49.693 65.517 2,985 0 0 923 OUTSIDE SERV 48.267 117 20.293 26.755 11,219 0 0 924 PROP INS 17.123 107 11.413 ° 5.710 0 0 0 925 1NJ 6 DAMAGE 177.076 117 74,448 98.155 4,473 0 0 926 EMPLOYEE BNFT 592.675 117 249,179 328.526 14,970 0 ., 0 928 REG COMM EXF 65.086 100 0 0 65.086 0 0 929 DUP CHGS -5.320 117 -2,237 -2.949 -134 0 0 930 MISC GEN 199.249 117 83.770 110,446 5.033 4 0 932 MAINT GEN PLT 108.014 106 71,088 37,726 0 0 0 Total z__rszzzzzzxz zzsxzssazaass zzxszzzzxzzc zzzzzzzzzxzsz zzszsrzzzsa--a -xsssssssasas ADMIN GENERAL 1.778.214 1184 749.805 923.232 105.177 0 0 41,166E 51.919E 5.915E O.000E O.00OE SUBTOTAL xxzsssaszszsa ------------- ------------- xzzsszaazsrzz ------------- -____-..--_-.- -------- --.----.cxcza aszsas:eases EXPENSES 4.628,677 1194 1.948,22E 2.503.272 177.177 0 10 42.090E 54.082E 3.828E 0.000E 0.000E PURCHASED POWER --------------- FACILITY CHG 29.904 3 29,904 0 0 0 0 a o DEMAND CHG 4.591.912 3 4.599.912 0 0 0 0 RATCHET DEMAND 775.464 2 775,464 0 0 0 0 to (D Subtotal ------------- ------------- ------------- ------------- ------------- ------------- cn : Demand PP 5.405.290 120T 5.405,280 0 10 0 0 0(D 100.000E 0.000% 0.000E 0.000% O.000Z = I- -h cr, ENEM 1.104.695 4 0 0 1.184,695 0 0 O FUEL 4 ADJSTMTS 6.796.292 . 0 0 6.796.292 0 0 Subtotal------------- ---------- - ------- ---- ------------- -- .. ---- --------- -- TOTAL ENERGY 7,980.987 1211 0 0 7.980,987 0 0 A AAA-/ A AAA-/ IAA AAA-/ A AAAY - A AAAY South Plains Electric Cooperative, Inc. Test Year Ended September 30, 1992 Present Rates CLASSIFICATION - EXPENSES ACCOUNTS -------------------- TOTAL DOLLARS A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE Total------------- ------------- ---- ------------- ------------- ------------ ------------- ----------- ------------- ------------- ------------- __== -------- PURCHASED POWER 13.386.267 1221 5.405.280 0 7.960.987 0 0 40.379Z 0.000% 59.621% 0.000% 0.0001 DEPRECIATION ------------ 403.5 TRANSMISSION 59.425 101 58.425 0 0 0 0 403.6 DISTRIBUTION 1,573.620 104 1,020.044 545,576 0 0 0 403.7 GENERAL 152.137 106 99.391 52.746 0 0 0 Total =-----=-----= __--______=_- =_=___==-===_ __-----__-_-- ____-__-____' DEPRECIATION 1.784.182 1231 1.185.060 598.322 0 0 0 66.465% . 33.535% 0.000% 0.0001 0.000% TAXES 408.1 PROPERTY 322.012 107 214.630 107,382 0 0 0 408.2/4 PAYROLL TAX 239.844 119 100,951 129.712 9.181 0 0 408.7 FRANCHISE 59.427 108 0 0 59.427 0 0 Total------------- ------------- ------------- --------_____ ------------- ------ TAXES 621.283 1241 315,591 237.094 68.60E 0 0 50.795% 38.162% 11.043% 0.0007 0.000% OTHER DEDUCTIONS ---------------- INTEREST CUST REPS 12,769 100 0 0 12,769 0 0 OTHER DEDUCTIONS 48,405 119 20.406 26.222 1.856 0 0 Total_____________ ------------- ------------- ------------- OTHER DEDUCTIONS 61.254 1251 20,406 26,222 14.625 0 0 33.316% 42.8081 23.876% 0.000Z 0.000% w n O TOTAL ca s to EXPENSES 20.481.663 1261 8,875,357 3,364.909 8,241.397 0 0 rn c 43.333% 16.429Z 40.2381 O.000Z 0.000% e (D x cn 0 South Plains Electric Cooperative, Inc, Test Year Ended SeDtesber 30, 1992 Present Rates CLASSIFICATION - RATE BASE ACCOUNTS -------------------- TOTAL DOLLARS ------------- A.F. DEMAND CUSTOMER ENERGY • FUEL REVENUE PLANT IN SERVICE 57,665,476 ---- 107 ------------- 38,435,670 -------------------------- 19.729,806 ------------- 0 ------------- 0 0 ACCUM DEPR TRANS -960.169 101 -960.169 0 0 0 0 ACCUM DEPR DIST -18,597,749 104 -12,149,891 -6,447,856 0 0 0 ACCUM DEPR GEN -1.777.954 106 -1.161.536 -616.418 0 0 0 Subtotal------------- ------------- -------------------------- ------------- ------------- NET PLANT 36,379,604 1271 24,164.074 12.165.530 0 0 0 66.513% 33,487% 0.000% 0.000% 0.000% MATLS 6 SUPPLIES 977,850 104 636,828 339.022 0 0 0 PREPAYMENTS 190,072 119 75.793 97.386 6.893 0 0 CASH WK CAP POWER 440,096 122 177,708 0 262.3BB 0 0 CASH WK CAP O6M 586.241 120 586.241 0 0 0 0 OUST REPS -167.681 108 0 0 -167.681 0 0 TOTAL------- -------------- ---•--•------ =__=__-===_=_ RATE BASE 38,346.182 1281 25.642,644 12,601,938 101,600 0 0 66.871% 32.064% 0.265% 0.000% 0.000% -Vcnn 0)no to S to (D M O- V C J 00 1 61 6 South Plains Electric C000erative, Inc. Test Year Ended September 30, 1992 Present Rates CLASSIFICATION - INTEREST ACCOUNTS -------------------- TOTAL DOLLARS A.F. DEMAND CUSTOMER ENERGY FUEL REVENUE INTEREST LTD ------------- 1.354,929 ------------------------------------------- 105 904,581 450,342 ------------- 0 ------------- 0 0 TOTAL=_=_ -=--_-_-- INTEREST 1,354.929 1291 904.587 450.342 0 0 0 66.763% 33.237% 0.000t 0.000% 0.000I -V V) n O+ 0 O un S En [D !D o. 00 C O CD -h 2 O U1 O COS Schedule 1-1.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE — PRESENT RATES YEAR ENDED SEPTEMBER 30, 1992 BILLING UNITS RATE REVENUE RESIDENTIAL Customer Charge 168,079 $6.00 $1.008,474 Energy Charge 116,184,233 $0.06866 7,977,209 PCRF Revenue 116,184,233 ($0.013948) (1,620,491) Subtotal $7,365,192 SPACE HEAT — SEPARATE METER Customer Charge 5,747 $0.00 $0 Energy Charge Nov —Apr 8,759,574 $0.04079 153,353 May —Oct 1.993,897 $0.06866 136,901 PCRF Revenue 5,753,471 ($0.013948) (80,247) Subtotal $210,007 SPACE HEAT — SINGLE METER Customer Charge 1,257 $6.00 $7,542 Energy Charge Nov —Apr 1ST500 kWH 1,055,430 $0.06866 72,466 Remaining Kwh 716,911 $0.04079 29,243 May —Oct All Kwh 287,581 $0.06866 19.745 PCRF Revenue 2,059.922 ($0.013948) (28,731) Subtotal $10%265 WATER HEATER Customer Charge 13,718 $6.00 $82,808 Energy Charge 1 ST 500 Kwh 6,957,135 $0.06866 477,677 Next 500 Kwh 5,058,220 $0.04919 248,814. Remaining Kwh 4,320,220 $0.06866 296,626 PCRF Revenue 16,335,575 ($0.013948) (227.842) Subtotal $877,583 SPACE HEAT — WATER HEATER/SPACE HEATER Customer Charge 4,821 $6.00 $28,926 Energy Charge Nov —Apr 1 ST 500 kWH 1,081,231 $0.06866 74,237 Next 500 Kwh 1,115,189 $0.04919 54,856 Remaining Kwh 3,010.592 $0.04079 122,802 May —Oct 1 ST 500 kWH 1,320.121 $0.06866 90,640 Next 500 Kwh 11011,300 $0.04919 49,746 Remaining Kwh 1,499,569 $0.06866 102,960 PCRF Revenue 9,038,002 ($0.013948) (126,058) Subtotal $398,109 TOTAL RESIDENTIAL 149,371,203 $8,951,156 Page 1 COS Schedule 1-1.0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE — PRESENT RATES YEAR ENDED SEPTEMBER 30, 1992 CONTROL 1 DAY/WEEK Total Bills Energy Charge July —Sept. 1 st 200 Kwh per HP Remaining Kwh Oct. —June All Kwh PCRF Revenue Annual Minimums Load Management Credits Subtotal TOTAL IRRIGATION GENERAL SERVICE Customer Charge Energy Charge General Use Space Heat Nov —Apr May —Oct PCRF Revenue Subtotal LARGE POWER — SCHOOLS & CHURCHES Customer Charge Demand Charge Energy Charge PCRF Revenue Subtotal LARGE POWER Customer Charge Demand Charge Energy Charge PCRF Revenue Subtotal COTTON GINS Customer Charge Demand Charge (Apr thru Sep) Energy Charge Apr —Sep All Kwh Oct —Mar 1 st 100 Kwh/KW Remaining Kwh PCRF Revenue S u btotal BILLING RATE REVENUE ai447 139,574 $0.13642 $19,041 96,396 $0.07716 7,438 63,100 $0.06728 4,245 299,070 ($0.012788) (3,825) 938 139,574 ($0.0125) (1,745) $26,093 36,001,833 $2,746,830 19,512 $17.95 $350,240 21,934,972 $0.07327 1,607,175 47,752 $0.04079 1,948 54,282 $0.07328 3,978 22,037,006 ($0.014190) (312,705) $1,650,636 300 $28.00 $8,400 30,117 $8.00 240,936 6,389,895 $0.04879 311,763 61389,895 ($0.014921) (95,344) $465,755 1,357 $28.00 $37.996 134.680 $8.00 1,077,440 40,485,371 $0.04879 1,975,281 40,485,371 ($0.014441) (584.649) $2,506,068 231 $28.00 $6,468 2,170 $8.00 17,360 233,590 $0.04879 11,397 4,341,265 $0.09299 403,694 8,124,724 $0.05108 415,011 12,699,580 ($0.017236) (218,890) $635,040 Page 3 T i - COS Schedule 1-1.0 SOUTH PLAINS ;ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE:+ PRESENT RATES YEAR ENDED SEPTEMBER 301992 BILLING UNITS RATE REVENUE' OILFIELD. = SECONDARY Total Qills 10,758 '.. Horsepower Charge " 231,591 $6.00. ;.;1,389,546 Energy Charge 317,074,314 $0.04793 '1:776,972 PCRF:Revenue„( 37,074,314 ($0.014455) (535,909) Subtotal i$21630,609 t" OILFIELD «. PRIMARY CustotnerCharge `: 256 $28.00 ii 57,168 Demand Charge 15,938 $7.75 A 23,520 r energy Charge 6,677,091 $0.04195 280,104 PCRF Revenue : ,.; 6,677,091 ($0.014517) (96,931) Subtbiw $313,860 F r LIGHTING Public Street Lights Customer Charge 36 $17.95 $646 rm Energy Charge . '. 371,189 $0.03858 14,320 PCRF Revenue 371,189 ($0.014344) (5,324) Outdoor lighting 6,000 Lumens (77 Kwh per llghiJ 75,449 $6.53 492,682 1.2 boo lumens (103 Kwh .Per Ught): .7.636 $9.53 72,771 PCRF Revenue ,. ; . 6,595,374 ($0.014344) : (94,604) Muitiple,iJnit Discount: 21-50 Lights ($0.25) Multil (Unit Discount: Ovre 50 V hts p 9 ($0.50) Equipment Rental — 6,000 Lumens 629 $2.87 2,379 Equipment Rental — 12,000 Lumens $4.55 r Subtotal . $482,871 OTHER REVENUE $127,704 TOTAL REVENUE 317.702.856 $20,510.529 r . rw COST-L30 Page 4 r 1. COS Schedule 1-1.1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE — PROPOSED RATES I YEAR ENDED SEPTEMBER 30, 1992 i BILLING UNITS RATE REVENUE r IRRIGATION NON —CONTROLLED Total Bills 47,598 !.. Energy Charge July —Sept. 1st 200 Kwh per HP 7,599,045 $0.13642 1,036,662 Remaining Kwh 7,701,201 $0.07845 604,159 r. Oct. —June All Kwh 5,200,623 $0.07150 371,845 Annual Minimums 55,970 PCRF Revenue 20,500,869 ($0.012788) (262,165) Subtotal $1,806,470 CONTROL ANYTIME Total Bills 15,942 Energy Charge July —Sept. 1 st 200 Kwh per HP 4,887,166 $0.13642 $666,707 Remaining Kwh 4,597,868 $0.07845 360,704 Oct. —June Ali Kwh 4,798,330 $0.07150 343,081 PCRF Revenue 14,283,384 ($0.012788) (182,656) Annual Minimums 11,143 �^ Load Management Credits 4,887,166 ($0.0375) (183,269) 1 Subtotal $1,015,710 CONTROL 3 DAYS/WEEK F— Total Bills 647 Energy Charge July —Sept. 1st 200 Kwh per HP 111,325 $0.13642 $15,187 Remaining Kwh 108,615 $0.07845 8,521 Oct. —June All Kwh 131,660 $0.07150 9,414 PCRF Revenue 351,600 ($0.012768) (4,496) Annual Minimums 834 Load Management Credits 111,325 ($0.0375) (4,175) Subtotal $25,285 CONTROL 2 DAYS/WEEK Total Bills 646 Energy Charge July —Sept. 1st 200 Kwh per HP 202,010 $0.13642 $27.558 Remaining Kwh 240,551 $0.07845 18,871 Oct. —June All Kwh 124,349 $0.07150 8,891 PCRF Revenue 566,910 ($0.012788) (7,250) Annual Minimums 1,928 Load Management Credits 202,010 ($0.0375) (7,575) Subtotal $42,423 1^ I Page 2 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE - PROPOSED RATES YEAR ENDED SEPTEMBER 30.1992 CONTROL 1 DAY/WEEK Total Bills Energy Charge July -Sept. 1st 200 Kwh per HP Remaining Kwh Oct. -June All Kwh PCRF Revenue Annual Minimums Load Management Credits Subtotal TOTAL IRRIGATION GENERAL SERVICE Customer Charge Energy Charge General Use Space Heat Nov -Apr May -Oct PCRF Revenue Subtotal LARGE POWER - SCHOOLS & CHURCHES Customer Charge Demand Charge Energy Charge PCRF Revenue Subtotal LARGE POWER Customer Charge Demand Charge Energy Charge 1 ST 200 Kwh/Kw Remaining Kwh PCRF Revenue Subtotal COTTON GINS Customer Charge Demand Charge (Apr thru Sep) Energy Charge Apr -Sep All Kwh Oct -Mar 1 st 100 Kwh/KW Remaining Kwh PCRF Revenue Subtotal BILLING UNITS 465 139,574 96,396 63,100 299,070 139,574 36,001,833 19,512 21,934,972 47,752 54,282 22,037,006 300 30,117 6,389,895 6,389,895 1,357 134,680 22,789,352 17,696,019 40,485,371 231 2,170 233,590 4,341,266 8,124,724 12,699,580 RATE $0.13642 $0.07845 $0.07150 ($0.012788) ($0.0375) $17.95 $0.07327 $0.04079 $0.07328 ($0.014190) COS Schedule 1-1.1 REVENUE $19,041 7,562 4,512 (3,825) 938 (5,234) $22,994 $2,912,883 $350,240 1,607,175 1,948 3,978 (312,705) $1,650,636 $28.00 $8,400 $8.00 240,936 $0.04879 311,763 ($0.014921) (95,344) $465,755 $50.00 $67,850 $8.00 1,077,440 $0.06519 1,485,638 $0.035 619,361 ($0.014441) (584,649) $2,665,639 $50.00 $11,550 $8.00 17,360 $0.05116 $0.09406 $0.05344 ($0.017236) 11,950 408,339 434.185 (218.890) $664,495 Page 3 r F COS Schedule 1-1.1 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PROOF OF REVENUE — PROPOSED RATES YEAR ENDED SEPTEMBER 30, 1992 BILLING UNITS RATE REVENUE OILFIELD — SECONDARY Total Bills 10,758 $ Horsepower Charge 231,591 $6.00 1,389,546 Energy Charge 37,074,314 $0.04793 1,776,972 PCRF Revenue 37,074,314 ($0.014455) (535,909) Subtotal $2,630,609 OILFIELD — PRIMARY Customer Charge 256 $50.00 $12,800 Demand Charge 15,938 $7.75 123,520 Energy Charge 6,677,091 $0.04239 283,042 PCRF Revenue 6,677,091 ($0.014517) (96,931) Subtotal $322,430 LIGHTING Public Street Lights Customer Charge 36 $17.95 $646 Energy Charge 371,189 $0,04130 15,330 PCRF Revenue 371,189 ($0.014344) (5,324) Outdoor Lighting 100 Watt High Pressure Sodium 18,862 $6.95 131,091 175 Watt Mercury Vapor 56,587 $6.95 393,280 150 Watt High Pressure Sodium 1,909 $10.00 19,090 400 Watt Mercury Vapor 5,727 $10.00 57,270 175 Watt Halide $6.95 400 Watt Halide $10.00 1000 Watt Halide $17.50 PCRF Revenue 6,595,374 ($0.014344) (94.604) Multiple Unit Discount: 21-50 Lights ($0.25) Multiple Unit Discount: Ovre 50 Lights ($0.50) Equipment Rental — 6,000 Lumens 829 $3.05 2,528 Equipment Rental — 12,000 Lumens $4.85 Subtotal $519,307 OTHER REVENUE $127.704 TOTAL REVENUE 317,702,856 $21,433,929 COSI-11 Page 4 RESIDENTIAL - REGULAR RATE RATE SCHEDULE: r t CUSTOMER CHARGE ENERGY CHARGE PCRF FACTOR PROOF OF REVENUE: CUSTOMER CHARGE ENERGY CHARGE PCRF FACTOR p k. BILLCOMPARISONS l pm 1 COULD M COS SOUTH PLAINS ELECTRIC COOPERATIVE, INC. Schedule J-1.0 EXISTING PROPOSED $6.00 $6.00 $0.06866 $0.07216 ($0.013948) ($0.013948) BILLING UNITS EXISTING PROPOSED 168,079 $1,008.474 $1,008,474 116,184,233 7,977,209 8,383,854 116,184,233 (1,620,491) (1,620,491) $7,365,192 $7,771,837 KWH INCREASE USAGE EXISTING PROPOSED $ % 50 8.74 8.91 0.17 2.00% 100 11.47 11.82 0.35 3.05% 200 16.94 17.64 0.70 4.13% 300 22.41 23.46 1.05 4.68% 400 27.88 29.28 1.40 5.02% 500 33.36 35.11 1.75 5.25% 750 47.03 49.66 2.63 5.58% 1,000 60.71 64.21 3.50 5.76% 1,500 88.07 93,32 5.25 5.96% 2,000 115.42 122.42 7.00 6.06% 31000 170.14 180.64 10.50 6.17% SOUTH PLAINS ELECTRIC COOPERATIVE, INC. RESIDENTIAL - SPACE HEAT - SEPARATE METER RATE SCHEDULE: EXISTING PROPOSED CUSTOMER CHARGE $0.00 $0.00 ENERGY CHARGE Nov -Apr $0.04079 $0.04433 May -Oct $0.06866 $0.07216 PCRF FACTOR ($0.013948) ($0.013948) PROOF OF REVENUE: BILLING UNITS EXISTING PROPOSED CUSTOMER CHARGE 5,747 $0 $0 ENERGY CHARGE Nov -Apr 3,759,574 153,353 166,662 May -Oct 1,993,897 136,901 143,880 PCRF FACTOR 5,753,471 (60,247) (80,247) $210,007 $230,294 BILL COMPARISONS COS Schedule J-2.0 KWH INCREASE USAGE EXISTING PROPOSED $ % November -April 50 1.34 1.52 0.18 13.19% 100 2.68 3.04 0.35 13.19% 200 5.37 6.08 0.71 13.19% 300 8.05 9.11 1.06 13.19% 400 10.74 12.15 1.42 13.19% 500 13.42 15.19 1.77 13.19% 750 20.13 22.79 2.66 13.19% 1,000 26.84 30.38 3.54 13.19% 1,500 40.26 45.57 5.31 13.19°% 2,000 53.68 60.76 7.08 13.19% 3,000 80.53 91.15 10.62 13.19% May -October 50 2.74 2.91 0.18 6.40% 100 5.47 5.62 0.35 6.40% 200 10.94 11.64 0.70 6.40% 300 16.41 17.46 1.05 6.40% 400 21.88 23.28 1.40 6.40% 500 27.36 29.11 1.75 6.40% 750 41.03 43.66 2.63 6.40% 1,000 54.71 58.21 3.50 6.40% 1,500 82.07 87.32 5.25 6.40% 2,000 109,42 116.42 7.00 6.40% 3,000 164.14 174.64 10.50 6.40% w• � SOUTH PLAINS ELECTRIC COOPERATIVE, INC. !� RESIDENTIAL - SPACE HEAT - SINGLE METER I RATE SCHEDULE: EXISTING PROPOSED �^^ CUSTOMER CHARGE $6.00 $6.00 ENERGY CHARGE ' Nov -Apr 1 ST 500 kwh $0.06866 $0.07216 Remaining Kwh $0,04079 $0.04433 May -Oct All KWH $0.06866 $0.07216 PCRF FACTOR ($0.013948) ($0.013948) r PROOF OF REVENUE: BILLING UNITS EXISTING PROPOSED CUSTOMER CHARGE 1,257 $7,542 $7.542 ENERGY CHARGE Nov -Apr 1 ST 500 kwh 1,055,430 72,466 76,160 Remaining Kwh 716,911 29,243 31,761 May -Oct All KWH 287,581 19,745 20,752 PCRF FACTOR 2,059,922 (28,731) (28,731) $100,265 $107,503 BILL COMPARISONS November -April r May -October P- cos".O i i k KWH USAGE ��ll►`L 8.74 11.47 16.94 22.41 27,88 33.36 40.07 46.78 60.20 73.62 100.46 PROPOSED 8.91 11.82 17.64 23.48 29.28 35.11 42.70 50.30 65.49 80.68 111.06 COS Schedule J-3.0 INCREASE 0.17 2.00% 0.35 3.05% 0.70 4.13% 1.05 4.68% 1.40 5.02% 1.75 5.25% 2.63 6.58% 3.52 7.53% 5.29 8.79% 7.06 9.59% 10.60 10.55% 50 8.74 8.91 0.17 2.00% 100 11.47 11.82 0.35 3.05% 200 16.94 17.64 0.70 4.13% 300 22.41 23.46 1.05 4.68% 400 27.88 29.28 1.40 5.02% 500 33.36 35.11 1.75 5.25% 750 47.03 49.66 2.63 5.58% 11000 60.71 64.21 3.50 5.76% 1,500 88.07 93.32 5.25 5.96% 2,000 115.42 122.42 7.00 6.W/o 3,000 170.14 180.64 10.50 6.17% i r- RESIDENTIAL - WATER HEATER t RATE SCHEDULE: r CUSTOMER CHARGE d ENERGY CHARGE 1ST 500 kWh Next 500 Kwh r Remaining Kwh PCRF FACTOR PM i PROOF OF REVENUE: CUSTOMER CHARGE �.. ENERGY CHARGE 1 ST 500 kwh Next 500 Kwh Remaining Kwh �• PCRF FACTOR BILLCOMPARISONS SOUTH PLAINS ELECTRIC COOPERATIVE, INC. EXGSTING PROPOSED $6.00 $6.00 COS Schedule J-4.0 $0.06866 $0.07216 $0.04919 $0.05272 $0.06866 $0.07216 ($0.013948) ($0.013948) BILLING UNITS EXISTING PROPOSED 13,718 $82,308 $82,308 6,957,135 477,677 502,027 5,058,220 248,814 266,669 4,320,220 296,626 311,747 16,335,575 (227,842) (227,842) $877,583 $934,909 KWH INCREASE USAGE EXISTING PROPOSED $ % 50 8.74 8.91 0.17 2.00% 100 11.47 11.82 0.35 3.05% 200 16.94 17.64 0.70 4.13°% 300 22.41 23.46 1.05 4.68% 400 27.88 29.28 1.40 5.02% 500 33.36 35.11 1.75 5.25°% 750 42.17 44.80 2.63 6.24% 1,000 50.98 54.49 3.52 6.90% 1,500 78.33 83.60 5.27 6.72% 2,000 105.69 112.70 7.02 6.64% 3,000 160.40 170.92 10.52 6.56°% SOUTH PLAINS ELECTRIC COOPERATIVE, INC. RESIDENTIAL - SPACE HEAT - WATER HEATER RATE SCHEDULE: EXISTING PROPOSED CUSTOMER CHARGE $6.00 $6.00 ENERGY CHARGE Nov -Apr 1 ST 500 kwh $0.06866 $0.07216 Nxt 500 Kwh $0.0492 $0.05272 Remaining Kwh $0.04079 $0.04433 May -Oct 1 ST 500 kwh $0.06866 $0.07216 Nxt 500 Kwh $0.0492 $0.05272 Remaining Kwh $0.06866 $0.07216 PCRF FACTOR ($0.013948) ($0.013948) PROOF OF REVENUE: BILLING UNITS EXISTING PROPOSED CUSTOMER CHARGE 4,821 $28,926 $28.926 ENERGY CHARGE Nov -Apr 1ST 500 kwh 1,081,231 74,237 78,022 Nxt 500 Kwh 1,115,189 54,856 58,793 Remaining Kwh 3.010.592 122,802 133.460 May -Oct 1ST 500 kwh 1,320,121 90,640 95,260 Nxt 500 Kwh 1,011.300 49,746 53,316 Remaining Kwh 1,499,569 102,960 108,209 PCRF FACTOR 9.038,002 (126,058) (126,058) $398,109 $429,926 BILL COMPARISONS November -April May -October cosis.0 COs Schedule J-5.0 KWH INCREASE USAGE EXISTING PROPOSED >b % 50 8.74 8.91 0.17 2.00% 100 11.47 11.82 0.35 3.05% 200 16.94 17.64 0.70 4,13% 300 22.41 23.46 1.05 4.68% 400 27.88 29.28 1.40 5.02% 500 33.36 35.11 1.75 5.25% 750 42.17 44.80 2.63 6.24% 11000 50.98 54.49 3.52 6.90% 1.500 64.40 69.68 5.28 8.21 % 2,000 77.82 84.87 7.06 9.07% 3.000 104.66 115.26 10.60 10.12% 50 8.74 8.91 0.17 2.00% 100 11.47 11.82 0.35 3.05% 200 16.94 17.64 0.70 4.13% 360 22.41 23.46 1.05 4.68% 4D0 27.88 29.28 1.40 5.02% 500 33.36 35.11 1.75 5.25% 750 42.17 44.80 2.63 6.24% 11000 50.98 54.49 3.52 6.90% 11500 78.33 83.60 5.27 6.72% 2,000 105.69 112.70 7.02 6.64% 3,000 160.40 170.92 10.52 6.56% ---I 7_1 --I -----7 ---I ---1 � _ _1 � _1 _-1 _� � � _� _ -- -1 _ A Cos Schedule J.6-0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. IRRIGATION NO CONTROL RATE SCHEDULE: ENERGY CHG PRESENT PROPOSED JULY-SEP 1 ST 200 KWH" $0.13642 $0.13642 ALL OVER $0.07716 $0.07845 OCT-JUN ALL KWH $0.06728 $0.07150 PCRF ($0.012788) ($0.012788) PROOF OF REVENUE: BILLING ENERGY CHG UNITS PRESENT PROPOSED JULY-SEP 1ST200KWH/I-A' 7,599,045 $1,036,662 $1,036,662 ALL OVER 7,701,201 594,225 604,159 OCT-JUN ALL KWH 5,200,623 349,898 371,845 PCRF 20,500,869 (262,165) (262,165) ANNUAL MINIMUMS 55,970 55,970 $1,774,589 $1,806,470 BILL COMPARISONS JUL-SEP OCT-JUN TOTAL JUL-SEP OCT-JUN TOTAL LOAD PRESENT PRESENT PRESENT PROPOSED PROPOSED PROPOSED INCREASE HP KVVH/HP FACTOR KWH RATE RATE RATE RATE RATE RATE $ % 25 100 18.4% 2,500 309.08 136.23 445.31 309.08 146.78 455.86 10.55 2.41/o 25 150 27.5% 3,750 463.62 204.35 667.97 463.62 220.17 683.79 15.82 2.41/o 25 200 36.7% 5,000 618.16 272.46 890.62 618.16 293.56 911.72 21.10 2.4% 25 250 45.9% 6,250 698.63 340.58 1,039.20 700.24 366.95 1,067.19 27.99 2.no 25 300 55.1 % 7,500 779.09 408.69 1,187.78 782.32 440.34 1,222.66 34.87 2.9% 25 350 64.31/o 8,750 859.56 476.81 1,336.36 864.39 513.73 1,378.12 41.76 3.1 % 25 400 73.5% 10,000 940.02 544.92 1,484.94 946.47 687.12 1,533.59 48.65 3.3% 25 450 82.6% 11,250 1,020.49 613.04 1,633.52 1,028.65 660.51 1,689.06 55.64 3.4% 25 500 91.8% 12,500 1,100.95 681.15 1,782.10 1,110.63 733.90 1,844.63 62.42 3.5% COST60 IRRIGATION ANYTIME CONTROL RATE SCHEDULE: ENERGY CHG JULY-SEP 1 ST 200 KWH/HP ALL OVER OCT-JUN ALL KWH LOAD CONTROOL CREDIT PCRF PROOF OF REVENUE: ENERGY CHG JULY-SEP 1 ST 200 KWH/HP ALL OVER OCT-JUN ALL KWH LOAD CONTROL CREDIT PCRF ANNUAL MINIMUMS BILL COMPARISONS LOAD HP KWH/HP FACTOR 25 100 18.4% 25 150 27.5% 25 200 36.7% 25 250 45.9% 25 300 55.1 % 25 350 84.3% 25 400 73.5% 25 450 82.6% 25 500 91.8% SOUTH PLAINS ELECTRIC COOPERATIVE, INC. PRESENT PROPOSED $0.13642 $0.13642 $0.07716 $0.07845 $0.06728 $0.07150 ($0.06) ($0.0375) ($0.012788) ($0.012788) BILLING UNITS PRESENT PROPOSED 4,887,166 $666,707 $666,707 4,597,888 354,773 360,704 4,798,330 322,832 343,081 4,887,166 (293,230) (183,269) 14,283,384 (182,656) (182.656) 11,143 11,143 $879,569 $1.015,710 JUL-SEP OCT-JUN TOTAL JUL-SEP OCT-JUN TOTAL PRESENT PRESENT PRESENT PROPOSED PROPOSED PROPOSED KWH RATE RATE RATE RATE RATE RATE 2,500 159.08 138.23 295.31 215.33 146.78 362.11 3,750 238.62 204.35 442.97 323.00 220.17 543.17 5,000 318.16 272.46 590.62 430.66 293.56 724.22 6,250 398.63 340.58 739.20 512.74 366.95 879.69 7,500 479.09 408.69 887.78 594.82 440.34 1,035.16 8,750 559.56 476.81 1,036.38 676.89 513.73 1,190.62 10,000 640.02 544.92 1,104.94 758.97 587.12 1,346.09 11,250 720.49 613.04 1,333.52 841.05 680.51 1,501.56 12,500 800.95 681.15 1,482.10 923.13 733.90 1.857.03 Cos Schedule J.7-0 INCREASE 66.80 22.6% 100.20 22.6% 133.60 22.6% 140.49 19.0% 147.37 16.6% 154.26 14.9% 161.15 13.6% 168.04 12.6% 174.92 11.8% CO&M Cos Schedule J.8-0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. IRRIGATION CONTROL 3 DAYS RATE SCHEDULE: ENERGY CHQ PRESENT PROPOSED JULY-SEP 1 ST 200 KWH/HP $0.13642 $0.13642 ALL OVER $0.07716 $0.07845 OCT-JUN ALL KWH $0.06728 $0.07150 LOAD CONTROL CREDIT ($0.0475) ($0.0375) PCRF ($0.012788) ($0.012788) PROOF OF REVENUE: BILLING ENERGY CHG UNITS PRESENT PROPOSED JULY-SEP 1ST 200 KWH/HP 111,325 $15,187 $15,167 ALL OVER 108,615 8,381 8,521 OCT-JUN ALL KWH 131,660 8,858 9,414 LOAD CONTROL CREDIT 111,325 (5,288) (4,175) PCRF 351,600 (4,496) (4,496) ANNUAL MINIMUMS 534 834 $23,478 $25,285 BILL COMPARISONS JUL-SEP OCT-JUN TOTAL JUL-SEP OCT-JUN TOTAL LOAD PRESENT PRESENT PRESENT PROPOSED PROPOSED PROPOSED INCREASE HP KWH/HP FACTOR KWH RATE RATE RATE RATE RATE RATE $ % 25 100 18.4% 2,500 190.33 136.23 326.56 215.33 146.78 362.11 35.55 10.9% 25 150 27.5% 3,750 285.50 204.35 489.84 323.00 220.17 543.17 53.32 10.9% 25 200 36.7% 5,000 380.86 272.46 653.12 430.66 293.56 724.22 71.10 10.9% 25 250 45.9% 6,250 461.13 340.58 801.70 512.74 366.95 879.69 77.99 9.7% 25 300 55.1% 7,500 541.59 408.69 950.28 594.82 440.34 1,035.16 84.87 8.9% 25 350 64.3% 8,750 622.06 476.81 1,098.86 678.89 513.73 1,190.62 91.78 8.4% 25 400 73.5% 10,000 702.52 544.92 1,247.44 758.97 587.12 1,346.09 98.65 7.9% 25 450 82.6% 11,250 782.99 613.04 1,396.02 041.05 660.51 1,501.56 105.54 7.6% 25 500 91.8% 12,500 863.45 681.15 1,544.60 923.13 733.90 1,657.03 112.42 7.3% COWN Cos Schedule J.9-0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. IRRIGATION CONTROL 2 DAYS RATE SCHEDULE: ENERGY CHG PRESENT PROPOSED JULY-SEP 1 ST 200 KWH/HP $0.13642 $0.13642 ALL OVER $0.07716 $0.07845 OCT-JUN ALL KWH $0.06728 $0.07150 LOAD CONTROL CREDIT ($0.030) ($0.0375) PCRF ($0.012788) ($0.012788) PROOF OF REVENUE: BILLING ENERGY CHG UNITS PRESENT PROPOSED JULY- SEP 1 ST 200 KWH/HP 202,010 $27,558 $27,558 ALL OVER 240.551 18,561 18,871 OCT-JUN ALL KWH 124,349 8,368 8,891 LOAD CONTROL CREDIT 202,010 (6,060) (7,575) PCRF 566,910 (7,250) (7,250) ANNUAL MINIMUMS 1,928 1,928 $43,103 $42,423 BILL COMPARISONS JUL-SEP OCT-JUN TOTAL JUL-SEP OCT-JUN TOTAL LOAD PRESENT PRESENT PRESENT PROPOSED PROPOSED PROPOSED INCREASE HP KWH/HP FACTOR KWH RATE RATE RATE RATE RATE RATE $ % 25 100 18.4% 2,500 234.08 136.23 370.31 215.33 148.78 362.11 (8.20) -2.2%' 25 150 27.5% 3,750 351.12 204.35 555.47 323.00 220.17 543.17 (12.30) -2.2% 25 200 36.7% 5,000 468.16 272.46 740.62 430.66 293.56 724.22 (16.40) -2.2% 25 250 45.9% 6,250 548.63 340.58 889.20 512.74 368.95 879.69 (9.51) -1.1 % 25 300 55.1% 7,500 629.09 408.69 1,037.78 594.82 440.34 1,035.18 (2.63) -0.3% 25 350 64.3% 8.750 709.56 476.81 1,186.36 676.89 513.73 1,190.62 4.26 0.4% 25 400 73.5% 10,000 790.02 544.92 1.334.94 758.97 587.12 1,346.09 11.15 0.8% 25 450 82.6% 11,250 670.49 613.04 1,483.52 841.05 660.51 1,501.56 18.04 1.2% 25 500 91.8% 12,500 950.95 681.15 1,632.10 923.13 733.90 1,657.03 24.92 1.5% cosm Cos Schedule J.10-0 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. IRRIGATION CONTROL 1 DAY RATE SCHEDULE: ENERGY CHG PRESENT PROPOSED JULY-SEP 1 ST 200 KVIM/HP $0.13642 $0.13642 ALL OVER $0.07716 $0.07845 OCT-JUN ALL KWH $0.06728 $0.07150 LOAD CONTROL CREDIT ($0.0125) ($0.0375) PCRF ($0.012788) ($0.012788) PROOF OF REVENUE: BILLING ENERGY CHG UNITS PRESENT PROPOSED JULY-SEP 1ST 200 KVVH/1-IP 139,574 $19,041 $19,041 ALLOVER 98,396 7,438 7,562 OCT-JUN ALL KWH 63,100 4,245 4,512 LOAD CONTROL CREDIT 139,574 (1,745) (5,234) PCRF 299,070 (3,825) (3,825) ANNUAL MINIMUMS 938 938 $26,093 $22,994 BILLCOMPARISONS JUL-SEP OCT-JUN TOTAL JUL-SEP OCT-JUN TOTAL LOAD PRESENT PRESENT PRESENT PROPOSED PROPOSED PROPOSED INCREASE HP MNH/HP FACTOR KWH RATE RATE RATE RATE RATE RATE T, % 25 100 18.41/o 2,500 277.83 136.23 414.06 215.33 146.78 362,11 (51.95) -12.5% 25 150 27.5% 3,750 416.75 204.35 621.09 323.00 220.17 543.17 (77.93) -12.5% 25 200 36.790 5,000 555.68 272.46 828.12 430.66 293.56 724.22 (103.90) -12.5-/o 25 250 45.9% 6,250 636.13 340.58 976.70 512.74 366.95 879.69 (97.01) -9.9% 25 300 55.1% 7,500 716.69 408.69 1,125.28 594.82 440.34 1,035.16 (90.13) -8.00/0 25 350 64.3% 8,750 797.06 476.81 1,273.86 676.89 513.73 1,190.62 (83.24) -6.51/o 25 400 73.5% 10,000 877.52 544.92 1,422.44 758.97 587.12 1,346.09 (76.35) -5.40/. 25 460 82.6% 11,250 957.99 613.04 1,571.02 841.05 660.51 1,501.66 (69.46) -4.41/6 25 500 91.81yo 12,500 1,038.45 681.15 1,719.60 923.13 733.90 1,657.03 (62.58) -&ffo 0031109 SOUTH PLAINS ELECTRIC COOPERATIVE, INC. LARGE COMMERCIAL RATE SCHEDULE: CUSTOMER CHARGE DEMAND CHARGE ENERGY CHARGE 1 ST 200/KWH/KW REMAINING KWH PCRF FACTOR PROOF OF REVENUE: CUSTOMER CHARGE DEMAND CHARGE ENERGY CHARGE 1 ST 200/KWH/KW REMAINING KWH PCRF FACTOR BILL COMPARISONS Cos Schedule J-11.0 EXISTING PROPOSED $25.00 $50.00 $8.00 $8.00 $0.04879 $0.06519 $0.035 ($0.014441) ($0.014441) BILLING UNITS EXISTING PROPOSED 1,357 $37.995 $67.850 134,680 1,077.440 1.077,440 40,485,371 1,975,281 22.789,352 1,485.638 17,696,019 819,361 40,485,371 (584,649) (584,849) $2,506,068 $2.665,639 KWH LOAD KWH INCREASE KW KWH/KW USAGE FACTOR USAGE EXISTING PROPOSED $ % 100 100 10.000 14% 10,000 $1.171A9 $1,357.49 $186.00 15.88% 100 200 20,000 27% 20,000 1,514.98 1,864.98 350.00 23.10% 100 300 30,000 41% 30,000 1,858.47 2,070.57 212.10 11.41% 100 400 40,000 55% 40,000 2,201.98 2,276.16 74.20 3.37% 100 500 50,000 68% 50,000 2,545.45 2,481.75 (63.70) —2.50% 200 100 20,000 14% 20,000 $2,314.98 $2,664.98 $350.00 15.12% 200 200 40,000 27% 40,000 3,001.96 3,679.98 678.00 22.59% 200 300 60,000 41% 60,000 3,688.94 4,091.14 402.20 10.90% 200 400 80,000 55% 80,000 4,375.92 4,502.32 126.40 2.89% 200 500 100,000 88% 100,000 5,062.90 4,913.50 (149.40) —2.95% cosnLo SOUTH PLAINS ELECTRIC COOPERATIVE, INC. COTTON GINS RATE SCHEDULE: Cos Schedule JA 2-0 PRESENT PROPOSED CUSTOMER CHARGE $28.00 $50.00 DEMAND CHG (APR-SEP) $8.00 $8.00 ENERGY CHG APR-SEP ALL KWH $0.04879 $0.05116 OCT-MAR 1ST 100 KWH/HP $0.09299 $0.09408 ALL OVER $0.05108 $0.05344 PCRF ($0.017238) ($0.017238) BILLING PROOF OF REVENUE: UNITS PRESENT PROPOSED CUSTOMER CHARGE 231 $9,488 $11,550 DEMAND CHG (APR-SEP) 2,170 17,300 17,300 ENERGY CHG APR -SEP ALL KWH 233,590 11,397 11,950 OCT-MAR 0 1ST 100 KWH/HP 4,341,268 403,894 408.339 ALL OVER 8,124,724 415,011 434,185 PCRF 12,899,580 (218,890) (218,890) 8,358,314 $635,040 $e64,495 BILL COMPARISONS OCT-MAR APR-SEP OCT-MAR APR -SEP OCT-MAR APR-SEP LOAD PRESENT PRESENT PROPOSED PROPOSED INCREASE INCREASE KW KWH/HP FACTOR KWH RATE RATE RATE RATE $ % $ % 400 100 18.4% 40,000 3,058.18 4,490.16 3,122.90 4,600.90 84.80 2.1 % 118.80 3.8% 400 150 27.5% 00,000 3,735.04 5,121.24 3,847.04 5.285.44 112.00 3.0% 194.20 4.4% 400 200 38.7% 80,000 4,411.92 5,752.32 4,571.12 5,983.92 159.20 3.8% 211.80 4.8% 400 250 45.9% 100,000 5,088.80 8,383.40 5,295.20 8,842.40 208.40 4.1 % 259.00 5.1 % 400 300 55.1 % 120,000 5,785.68 7,014.48 8,019.28 7.320.88 253.80 4.4% 308.40 5.3% 400 350 04.3% 140,000 6,442.58 7,045.56 8,743.38 7,999.38 300.80 4.7% 353.80 5.5% 400 400 73.5% 160,000 7,119.44 8,278.84 7,467.44 8,677.84 348.00 4.9% 401.20 5.e% 400 450 82.6% 180,000 7,796.32 8,907.72 8,191.52 9,358.32 395.20 5.1% 448.80 5.8% 400 500 91.8% 200,000 8.473.20 9,538.80 8,915.80 10,034.80 442.40 5.2% 498,00 5.9% 800 100 18.4% 60,000 4,573.24 8,721.24 4,659.44 6,885.44 80.20 1.9% 164.20 3.0% 800 150 27,5% 90,000 5,588.58 7,887.88 5,745.58 7,903.18 157.00 2.8% 235.30 4.2% 800 200 38.7% 120,000 0,803.88 8,814.48 8,831.88 8,920.88 227AO 3.4% 308.40 4.8% 800 250 45.9% 150,000 7,819.20 9,581.10 7,917.80 9,938.80 298.e0 3.9% 377.50 5.0% 800 300 55.1% 180,000 8,034.52 10,507.72 9,003.92 10,950.32 369.40 4.3% 448.00 5.2% 000 350 84,3% 210,000 9,049.84 11,454.34 10,090.04 11,974.04 440.20 4.6% 519.70 5.4% 800 400 73.5% 240,000 10,885.18 12,400.90 11,178.18 12,991.78 511.00 4.8% 590.80 5.5% 800 450 82.8% 270,000 11,680.49 13,347.58 12,262.28 14,009.48 581.80 5.0% 861.90 5.7% 800 500 91.8% 300,000 12,895.80 14,294.20 13,348.40 15,027.20 052.80 5.1 % 733.00 5.8% COMM r E SOUTH PLAINS ELECTRIC COOPERATIVE, INC. OILFIELD PRIMARY RATE SCHEDULE - CUSTOMER CHARGE DEMAND CHARGE ENERGY CHARGE PCRF FACTOR PROOF OF REVENUE: CUSTOMER CHARGE DEMAND CHARGE ENERGY CHARGE PCRF FACTOR BILL COMPARISONS 1 s. cmim s 1. l i, i. COS Schedule J-13.0 PRESENT PROPOSED $28.00 $50.00 $7.75 $7.75 $0.04195 $0.04239 (60.014517) ($0.014517) BILLING UNITS PRESENT PROPOSED 256 $7,168 $12,800 15,938 123,520 123,520 6,677.091 280,104 283,042 6,677,091 (96.931) (96,931) $313AW $322.430 KWH LOAD INCREASE KW USAGE FACTOR EXISTING PROPOSED $ % 75 10,950 20% $909.64 $936.46 $26.82 2.95% 75 16,425 30% 1,059.84 1,089.06 29.23 2.76% 75 21,900 40% 1,210.03 1,241.67 31.64 2.61 % 75 27,375 50% 1,360.23 1,394.27 34.05 2.50% 75 32,8W 60% 1,510,42 1,546.88 36.45 2.41% 100 14,600 20% $1,203.52 $1,231.95 $28.42 2.36% 100 21,9W 30% 1,403.78 1,435.42 31.64 2.25% 100 29,200 40% 1,604.04 1,638,89 34.85 2.17% 100 36,500 50% 1,804.30 1,842.36 38.06 2.11 % 100 43,800 60% 2,004.57 2,045.64 41.27 2.06% SOUTH PLAINS ELECTRIC COOPERATIVE, INC. LIGHTING PROOF OF REVENUE: BILLING PUBLIC STREET LIGHTS UNITS MONTHLY CHARGE 36 ENERGY CHARGE 371.189 PCRF 371,189 OUTDOOR LIGHTING 6,000 LUMENS 75,449 12,000 LUMENS 7.636 EQUIPMENT RENTAL 6,000 LUMENS 829 12,000 LUMENS MULTIPLE UNIT DISCOUNT - 21-50 LIGHTS MULTIPLE UNIT DISCOUNT - OVER 50 LIGHTS PCRF 6.595.374 BILL COMPARISONS oosn" COS Schedule J-14.0 PRESENT PROPOSED RATE REVENUE RATE REVENUE $17.95 $646 $17.95 $646 $0.03858 14,320 $0.04130 15,330 ($0.014344) (5,324) ($0.014344) (5,324) $6.53 492,682 $6.95 524,371 $9.53 72,771 $10.00 76,360 $2.81 2,379 $3.05 2,528 $4.55 $4.85 ($0.25) ($0.25) ($0.50) ($0.50) ($0.014344) (94.604) ($0.014344) (94,604) $482,871 $519,307 ASSIGNED INCREASE KWH EXISTING PROPOSED $ % PUBLIC STREET LIGHTS 6,000 LUMEN 77 $19.82 $20.03 0.21 1.06% 12,000 LUMEN 103 $20.45 $20.73 0.26 1.37% OUTDOOR LIGHTS 6,000 LUMEN 77 $5.43 $5.65 0.42 7.74% 12,000 LUMEN 103 $8.05 $8.52 0.47 5.84% RENTAL 6,000 LUMEN 2.87 3.05 0.18 6.27% 12,000 LUMEN 4.55 4.85 0.30 6.59%