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Anc Fairbanks Intertie Committe Operating Minutes 1986
NAME John S.Cooley Mike Massin Tom Lovas Ray Duncan Jim Hall Ken Ritchey Sam Matthews Larry Colp Alan Martin Bob Orr Marvin Riddle Donald L.Shira Afzal H.Khan "4132/413/3 INTERTIE OPERATING COMMITTEE REPRESENTING Municipal Light & Power Chugach Electric Association Matanuska Electric Association Alaska Electric Generation and Transmission Cooperative Fairbanks Municipal Utilities System Golden Valley Electric Alaska Power Authority MAILING ADDRESS 1200 E.First Avenue Anchorage,AK 99501 P.O.Box 196300 Anchorage AK 99519 P.O.Box 2929 Palmer,AK 99645 P.O.Box 169 Homer,AK 99603 Box 2215 Fairbanks,AK 99707 Box 1249 Fairbanks,AK 99707 P.O.Box 190869 Anchorage,AK 99519 Gv PHONE (907)279-7671 (907)563-7494 (907)745-3231 (907)235-8167 (907)456-1000 (907)452-1151 (907)561-7877 ALASKA INTERTIE OPERATING COMMITTEE SUBCOMMITTEES I.Relay/Protection Subcommittee Il.Handbook/Procedures Subcommittee III.Machines/Rating Subcommittee IV.Reserves/Load Shed Subcommittee V.S.V.S.Evaluation Subcommittee VI.S.C.A.D.A./Metering/Communication Subcommittee VII.Dispatch/Scheduling Subcommittee x,Chairman Vacant Chairmanship. 0342/774/9 *John Marshall Jim Hall Larry Hembree Afzal Khan Steve Haagenson *Sam Matthews Mike Massin Bob Orr *George Roser Hank Nikkels Frank Abbegg III Alan Martin *Marvin Riddle Ray Duncan Hank Nikkels Larry Hembree Alan Martin Afzal Khan John Marshall Bob Orr John Cooley Dave Barden *Bob Orr Marvin Riddle John Cooley Robert Day Afzal Khan Jim Hall Ray Duncan Alan Martin *Marvin Riddle Ray Duncan John Cooley Doug Hall Alan Martin Ernie Jamison Dave Barden VITI. IX. XI. XII. ALASKA INTERTIE OPERATING COMMITTEE SUBCOMMITTEESPAGETWO Budget Subcommittee Load/Resources Subcommittee Dispatcher/Training Subcommittee Reliability/Criteria Subcommittee Insurance Subcommittee *Chairman. 0342/774/10 *Mike Massin Bob Orr John Marshall *John Marshall Bob Orr Mike Massin Sam Matthews *Marvin Riddle Ray Duncan John Cooley Ernie Jamison Alan Martin Larry Wolf John Aspnes *Sam Matthews Jim Hall Larry Colp Larry Hembree John Marshall Steve HaagensonAfzalH.Khan *Don Shira Bob Hansen Tom Lovas Ken Ritchey Virgil Gillespie Jerry Truskowski Sam Matthews ML&P GVEA CEA CEA GVEA ML&P AEG&T GVEA CEA ML&P AEG&T FMUS APA UAF AEG&T AEG&T FMUS ML&P CEA GVEA APA APA GVEA CEA MEA FMUS ML&P MEA NAME John S.Cooley Mike Massin Tom Lovas Ray Duncan Jim Hall Ken Ritchey Sam Matthews Larry Colp Alan Martin Bob Orr Marvin Riddle Donald L.Shira Afzal H.Khan 4132/413/3 INTERTIE OPERATING COMMITTEE REPRESENTING Municipal Light & Power Chugach Electric Association Matanuska Electric Association Alaska Electric Generation and Transmission Cooperative Fairbanks Municipal Utilities System Golden Valley Electric Alaska Power Authority MAILING ADDRESS 1200 E.First Avenue Anchorage,AK 99501 P.O.Box 196300 Anchorage AK 99519 P.O.Box 2929 Palmer,AK 99645 P.O.Box 169 Homer,AK 99603 Box 2215 Fairbanks,AK 99707 Box 1249 Fairbanks,AK 99707 P.O.Box 190869 Anchorage,AK 99519 PHONE (907)279-7671 (907)563-7494 (907)745-3231 (907)235-8167 (907)456-1000 (907)452-1151 (907)561-7877 ALASKA INTERTIE OPERATING COMMITTEE SUBCOMMITTEES I.Relay/Protection Subcommittee II.Handbook/Procedures Subcommittee III.Machines/Rating Subcommittee IV.Reserves/Load Shed Subcommittee V.S.V.S.Evaluation Subcommittee VI.S.C.A.D.A./Metering/Communication Subcommittee VII.Dispatch/Scheduling Subcommittee a Chairman Vacant Chairmanship. 0342/774/9 *John Marshall Jim Hall Larry Hembree Afzal Khan Steve Haagenson *Sam Matthews Mike Massin Bob Orr *George Roser Hank Nikkels Frank Abbegg III Alan Martin *Marvin Riddle Ray Duncan Hank Nikkels Larry Hembree Alan Martin Afzal Khan John Marshall Bob Orr John Cooley Dave Barden *Bob Orr Marvin Riddle John Cooley Robert Day Afzal Khan Jim Hall Ray Duncan Alan Martin *Marvin Riddle Ray Duncan John Cooley Doug Hall Alan Martin Ernie Jamison Dave Barden CEA MEA ML&P APA GVEA AEG&T ML&P GVEA CEA ML&P GVEA FMUS GVEA CEA ML&P ML&P FMUS APA CEA GVEA ML&P AEG&T GVEA GVEA ML&P ML&P APA AEG&T CEA FMUS GVEA CEA ML&P ML&P FMUS AEG&T AEG&T VIII. IX. XI. XII. ALASKA INTERTIE OPERATING COMMITTEE SUBCOMMITTEES PAGE TWO Budget Subcommittee Load/Resources Subcommittee Dispatcher/Training Subcommittee Reliability/Criteria Subcommittee Insurance Subcommittee *Chairman. 0342/774/10 *Mike Massin Bob Orr John Marshatl *John Marshall Bob Orr Mike Massin Sam Matthews *Marvin Riddle Ray Duncan John Cooley Ernie Jamison Alan Martin Larry Wolf John Aspnes *Sam Matthews Jim Hall Larry Colp Larry Hembree John Marshall Steve HaagensonAfzalH.Khan *Don Shira Bob Hansen Tom Lovas Ken Ritchey Virgil Gillespie Jerry Truskowski Sam Matthews ML&P GVEA CEA CEA GVEA ML&P AEG&T GVEA CEA ML&P AEG&T FMUS APA UAF AEG&T AEG&T FMUS ML&P CEA GVEA APA APA GVEA CEA MEA FMUS ML&P MEA Distribution List September 17,1987 Mr.Michael P.Kelly General Manager Golden Valley Electric Association P.O.Box 1249 Fairbanks,Alaska 99707 Mr.Richard Newland General Manager Chugach Electric Assocation P.O.Box 196300 Anchorage,Alaska 99519-6300 Mr.James Palin General Manager Matanuska Electric Assocaition P.O.Box 2929 Palmer,Alaska 99645 Mr.Virgil Gillespie General Manager Fairbanks Municipal Utility Systems P.0.Box 2215 Fairbanks,Alaska 99707 Mr.Tom Stahr General Manager Anchorage Municipal Light &Power 1200 East First Avenue Anchorage,Alaska 99501 Mr.Kent Wick General Manager Homer Electric Association P.0.Box 429 Homer,Alaska 99603 Il. Ill. IV. VI. VII. ANCHORAGE FAIRBANKS INTERTIE OPERATING COMMITTEE - SUBCOMMITTEES Relay/Protection Subcommittee Handbook/Procedures Subcommittee Machines/Rating Subcommittee **vacant chairmanship Reserves/Load Shed Subcommittee S.V.S.Evaluation Subcommittee **vacant chairmanship S.C.A.D.A./Metering/ Communications Subcommittee Dispatch/Scheduling Subcommittee Rev.10/9/85 1555/468 Page 1 *John Marshal] Jim Hall Larry Hembree Afzal Khan Steve Haagenson *Sam Matthews Mike Massin Bob Orr Stan Steczkowski George Roser Hank Nikkels Frank Abbegg III Alan Martin *Marvin Riddle Ray Duncan Howard Thacke Hank Nikkels Larry Hembree Alan Martin Afzal Khan John Marshall Dave Shaeffer Harry Beck Bob Orr John Cooley Dave Barden *Bob Orr John Cooley Afzal Khan Jim Hall Ray Duncan Marvin Riddle Robert Day Alan Martin *Marvin Riddle John Cooley Ray Duncan Alan Martin Ernie Jamison Dave Barden Kcpeoeaee CEA MEA ML&P APA GVEA HEA ML&P GVEA APA Ad. CEA ML&P GVEA FMUS GVEA CEA APA ML&P ML&P FMUS APA CEA G.C.A. APA GVEA ML&P AEG&T GVEA ML&P APA AEG&T CEA GVEA ML&P FMUS GVEA ML&P CEA FMUS AEG&T AEG&T *Anchorage/Fairbanks Intertie Operating Committee Subcommittee VIII.Budget Subcommittee IX,Load/Resources Subcommittee X,Dispatcher/Training Subcommittee XI.Reliability/Criteria Subcommittee *Chairman Rev.10/9/85 1555/468 Page 2 *Mike Massin John Marshall Bob Orr *John Marshall Bob Orr Mike Massin Sam Matthews *Marvin Riddle Ray Duncan John Cooley Ernie Jamison Stan Sieczkowski Alan Martin Larry Wolf John Aspnes *Sam Matthews Larry Colp Larry Hembree John Marshall Jim Hall Harry Beck Steve Haagenson ML&P CEA GVEA CEA GVEA ML&P AEG&T GVEA CEA ML&P AEG&T APA Ad. FMUS APA U.A.F. AEG&T FMUS ML&P CEA AEG&T APA GVEA Apertecte------- ALASKA INTERTIE -OPERATING COMMITTEE - SUBCOMMITTEES _w.Relay/Protection Subcommittee *John Marshall CEA Jim Hall MEA Larry Hembree ML&P Afzal Khan APA Steve Haagenson GVEA II.Handbook/Procedures Subcommittee *Sam Matthews AEG&T Mike Massin ML&P Bob Orr GVEA III.Machines/Rating Subcommittee *George Roser CEA Hank Nikkels ML&P Frank Abbegg III GVEA Alan Martin FMUS IV.Reserves/Load Shed Subcommittee '*Marvin Riddle GVEA .Ray Duncan CEA Howard Thacke APA Hank Nikkels ML&P Larry Hembree ML&P Alan Martin FMUS -V.§.V.S.Evaluation Subcommittee Afzal Khan APA John Marshall CEA Harry Beck APA **vacant chairmanship Bob Orr GVEA John Cooley ML&P Dave Barden AEG&T VI.S.C.A.D.A./Metering/Communications *Bob Orr GVEA Subcommittee Marvin Riddle GVEA John Cooley ML&P Robert Day ML&P Afzal Khan APA Jim Hall AEG&T Ray Duncan CEA Alan Martin FMUS VII.Dispatch/Scheduling Subcommittee *Marvin Riddle GVEA ;Ray Duncan CEA John Cooley ML&P Doug Hal]ML&P Alan Martin FMUS Ernie Jamison AEG&T Dave Barden AEG&T VIII.Budget Subcommittee *Mike Massin ML&P 9894/482/8 (ENBob Orr -John Marshall IX.Load/Resources Subcommittee *John Marshall Bob Orr Mike Massin Sam Mathews X.Dispatcher/Training Subcommittee *Marvin Riddle Ray Duncan John Cooley Ernie Jamison Alan Martin Larry Wolf John Aspnes XI.Reliability/Criteria Subcommittee *Sam Matthews Jim Hall Harry Beck Larry Colp Larry Hembree John Marshall Steve Haagenson *Chairman Revised 10/9/85 Effective November 1985 9894/482/9 GVEA CEA CEA GVEA ML&P AEG&T GVEA CEA ML&P AEG&T FMUS APA (State) U.A.F. AEG&T AEG&T APA FMUS ML&P CEA GVEA ALASKA INTERTIE OPERATING COMMITTEE MEETING MINUTES Attendance: Sam Mathews Harry L.Beck WEDNESDAY,NOVEMBER 12,1986 (AT CHUGACH ELECTRIC ASSOCIATION) Alaska Electric &Generation Cooperative (AEG&T) Alaska Power Authority (APA) Ed Morris Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power (ML&P) Ray Duncan Chugach Electric Association (CEA) Brad Evans Chugach Electric Association John Marshall Chugach Electric Association Mike Ridge Division of Telecommunications (DIVCOM) Bob Orr Golden Valley Electric Association (GVEA) Marvin Riddle Golden Valley Electric Association Larry Colp Fairbanks Municipal Utilities System The meeting was called to order by Chairman John Cooley at 9:00 a.m.in the Electrical Engineering Conference Room at Chugach Electric Association.Attending as a visitor by request of the Committee was Mike Ridge,Division of Communications (DIVCOM) Minutes of the September 17,1986 meeting were distributed.The Chairman indicated that on p.2,paragraph 3,"Dispatch Scheduling"should be replaced with "Relaying".The Chairman then stated that on p.6, paragraph 1,"RELAYING"should be replaced with "RELIABILITY."Chairman Cooley corrected the directions to meet and discuss relay settings. Chairman John Cooley asked if there were any additional corrections or amendments that should be made to them.There were none.John Marshall moved that the minutes be approved as corrected.The motion was seconded by Bob Orr and the motion was passed unanimously by those present. The agenda was then modified by inserting under New Business,"G.NERC Review"and "H.FY88 Budget". Marvin Riddle reported on the meetings of the Dispatch Scheduling Subcommittee conducted on October 8,1986 and again on November 6,1986. Minutes of the November 6 meeting were distributed and read by Marvin Riddle.From the October 8 meeting,he indicated that the subcommittee had examined hour-by-hour reserve deficiency reporting but that it didn't work effectively.He stated that the subcommittee was recommending that a test hour approach to reserve deficiency accounting be adopted. From the November 6 meeting,Marvin Riddle reported on the October 16, 1986 test of the Intertie.This test demonstrated the ability to serve part of the MEA load at Teeland from the Northern control area.See attached supplement to subcommittee minutes.Marvin Riddle concluded that the Northern control area could serve the Southern area down to Pt. 7284/654 Alaska Intertie Operating Committee Meeting Minutes November 12,1986 Page 2 MacKenzie to provide startup power in the event of Southern area outage.He will forward a copy of a letter from Jim Hall,MEA on the pickup of load from the north.The letter was to be included with the minutes. John Marshall then presented the report on the November 7,1986 meeting of the Reliability/Criteria Subcommittee.Minutes of the meeting were distributed and discussed by John Marshall.He indicated that after the subcommittee meeting,a workshop was conducted to examine the accuracy and adequacy of the data that UAF had received from the utilities.He indicated that corrected data (where deficiencies had been identified) were to be provided to UAF by November 13,1986. Bob Orr stated that it was necessary for someone to be designated in-charge to ensure that the utilities and UAF are working together.He objected to release of any data without specific approval of the utilities.Harry Beck stated that he thought Dr.George Mulligan had been designated by UAF to be the central point of contact for this project.John Marshall concurred with this statement by saying that'he thought Dr.Mulligan was coordinating this effort.John Cooley stated that he would contact Dr.Aspnes to consult him on this question. John Marshall then reported on the expected analysis by UAF of thefeasibilityofadoptingtheElectroconsoftware(and eliminating the EPRI code from the database)should this software be provided to them from the Anchorage-Kenai Transmission Intertie Feasibility Study project group.John Marshall indicated that this analysis is expected to be complete by the end of January 1987 conditioned upon delivery of the Electrocon software to UAF by the end of November 1986. Under APA Intertie Status Update,Harry Beck indicated that the Board ofMatanuskaElectricAssociation(MEA)had approved the Transmission Service Agreement.Bob Orr stated that it is necessary to develop the transmission service rate for FY87 using the projections for Intertie usage with the MEA base load at Douglas substation applied to the calculation. Harry Beck reported that comments have not been received yet from Gilbert Commonwealth concerning the Intertie test. Mike Ridge from DIVCOM then presented a report on the activities of his agency in regards Intertie communications work as detailed in the letterfromAlaskaPowerAuthoritytoDIVCOMdatedOctober21,1986 (attached). He said that his crew would be at the Teeland substation the following week to begin the work to complete the data link triangle between the CEA,GVEA and ML&P dispatch centers.He indicated that DIVCOM would meet with UAF and GVEA to plan the implementation of all equipment necessary to interconnect all UAF data acquisition equipment at theTeeland,Healy and Gold Hill substations.Mike Ridge stated that DIVCOMwouldprovidethevoicechanneltointerconnecttheCEA,GVEA and ML&Pdispatchcentersaspreviouslyrequested.Finally,he informed the Committee that the VHF repeater at Reindeer Hill,required to support 7284/654 Alaska Intertie Operating Committee Meeting Minutes November 12,1986 Page 3 GVEA maintenance activities on the Intertie,would-be installed in March or April of 1987. There were no other visitors present at the meeting. There was no Old Business. Under New Business,the Committee went into work session at 11:30 a.m. Under Dispatch Scheduling,the test-hour method for the accounting of spinning reserve deficiencies was discussed.Marvin Riddle discussed the sample calculation attached to the minutes of the Dispatch Scheduling subcommittee.Marvin Riddle indicated that the test-hour method appeared to be the best method of spinning reserve deficiency accounting.Bob Orr stated that the data should be checked to see if the time of system peak loading is when the reserve deficiencies are most likely to occur.Marvin Riddle stated that he would check a fullday's data for a two week period to determine the relationship between system loading and spinning reserve deficiencies.Finally,Bob Orr said that the Operating Committee needs an update from the SCADA/Communications subcommittee on the status of the use and present capabilities of the data link. Under Reliability/Criteria,John Marshall recommended that the submitted 10 power flow and 3 stability case studies by approved by the Operating Committee.Bob Orr again stressed the need for the Engineer/Coordinator of this project to provide monthly updates to the Operating Committee on the work of UAF.Chairman John Cooley indicated that he would call Dr. Aspnes (UAF)and so notify him.Harry Beck suggested that the Reliability/Criteria subcommittee meet the first week of December to review the data base with UAF representatives. Under Relaying,discussion focused on the specific Operating Guidelines that had been approved by the Operating Committee.Bob Orr indicated that the Relaying subcommittee should review NERC Operating Practice #14, Discussion then turned to Insurance.Ed Morris said that the State of Alaska may be able to sell bonds to cover casualty insurance for the Intertie but that this would require legislative approval.He said that only the substations are presently covered and that the Operating Committee can determine the criteria for providing coverage for all or a portion of the transmission line under a bond sale.Bob Orr said that it was not the Operating Committee's function to determine this level of coverage. Harry Beck stated that he had not seen any of the Participants'proof of insurance coverage with the exception of those of the Power Authority and Municipal Light &Power.Ed Morris concurred with this statement.Bob Orr asked if the Operating Committee was responsible for reviewing these insurance documents.John Cooley and Marvin Riddle answered "yes ." 7284/654 Alaska Intertie Operating Committee Meeting Minutes November 12,1986 Page 4 Ed Morris then asked for comments on the Power Authority discussion papers presented at the preceding Operating Committee meeting.Ed Morris then requested that each member discuss these papers with their respective managers.He indicated that he would formally request,by letter,that the general managers review the issue of funding insurance coverage by the sale of bonds and respond to the Power Authority.He further indicated that these letters would be submitted within two weeks time. Under NERC review,the letter from CEA to GVEA dated October 2,1986 was discussed.Ray Duncan stated that it was his understanding that the NERC review of the interconnected system operating procedures could be provided at no cost to the utilities.John Cooley said that if this review process can be provided at no cost to the users then the Operating Committee should request that NERC perform this review.Ray Duncan said that he would report back to the Operating Committee on the costs,if any,associated with this review process. Under FY88 Budget,Chairman read a letter from the Power Authority to the Operating Committee requesting that all Participants submit their FY88 Intertie budget material to the Power Authority by December 15, 1986.Ed Morris stated that it had been necessary for the Power Authority to provide a figure for total estimated Intertie expendituresforFY88totheStateOfficeofManagement&Budget (OMB).When questioned about the preparation of a monthly management report for the Intertie Participants,Ed Morris stated that the State's transition team's activities had prevented the Power Authority's accounting department from performing its work on developing this report.He said that the Power Authority hopes to resume its work in this area soon. Bob Orr stated that each Participant was only allowed one alternate at the Operating Committee.Harry Beck indicated that he would provide a new list of delegates and alternates to the Committee as an attachment to this month's meeting minutes. At 1:30 p.m.,under formal Operating Committee action,Chairman John Cooley entertained a motion to adopt the 10 power flow and 3 stability cases recommended by the Reliability/Criteria subcommittee as formal cases for study by UAF as a part of the work of the Power Flow and Stability Analysis Agreement.The motion was so moved by Sam Mathews and seconded by Larry Colp.The motion was adopted unanimously. The Chairman then directed all representatives that have been contacted by UAF in regards the Data Base Management Project to complete theirreviewoftheirrespectivesystem's data base and submit same to UAF by October 1,1986. The Chairman then directed the DISPATCH SCHEDULING SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to review the work concerning the development of a system for spinning reserve deficiency accountingandreportingpriortothenextOperatingCommitteemeeting. 7284/654 Alaska Intertie Operating Committee Meeting Minutes November 12,1986 Page 5 The Chairman then directed the SCADA/COMMUNICATIONS SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to review the progress of the work concerning the development of data lists for the data link. The Chairman then directed the RELIABILITY/CRITERIA SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to review the work of UAF concerning the development of the interconnected system data base.The Chairman directed the Subcommittee to meet early in December prior to the studies being performed for the Interties. The Chairman then directed the RELAYING SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to review and consider the adoption of the procedures contained in the NERC Operating Guideline #14. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,JANUARY 14,1987 AT 9:00 A.M.IN THE CONFERENCE ROOM AT ANCHORAGE MUNICIPAL LIGHT &POWER AT 1200 E.FIRST AVE.,ANCHORAGE,ALASKA. Larry Cop then motioned for the meeting to adjourn.Harry Beck seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 1:50 p.m. Sincerely, Edwin L.Morris,Secretary Alaska Intertie Operating Committee ELM/HB:kyf Attachments: 1.January meeting agenda 2.Letter from Chugach Electric Assn.to Golden Valley Electric Assn. dated October 2,1986. Letter from Alaska Power Authority to Division of Telecommunications dated October 21,1986. Letter from Alaska Power Authority to Division |of Telecommunications dated October 23,1986. Letter from Alaska Power Authority to Alaska Intertie Operating Committee dated October 31,1986. 6.Alaska Intertie Operating Committee list,"Designated Representatives and Alternates"dated December 1986.7.Minutes of Dispatch Scheduling meetings of October 8,1986 and November 6,1986. 8.Minutes of Reliability/Criteria meeting of November 6,1986. 9.Letter from Alaska Power Authority to Alaska Intertie Operating Committee dated November 5,1986.no>WwW7284/654 O ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,JANUARY 14,1987 BEGIN at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda Ill.Committee correspondence and reports A. Dispatch/Scheduling Subcommittee B.Reliability Subcommittee C.Relaying Subcommittee D.SCADA/Communications E.Intertie Status Update (A.P.A.) IV.Visitor comments related to items on agenda V.Old Business VI.New Business A.Recess and work session B.Dispatcher/Scheduling C.Reliability D.Relaying Subcommittee E.SCADA/Communications F.Insurance G.Others VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Meeting location:Anchorage Municipal Light and Power 1200 East First Avenue Anchorage,Alaska 99501 279-7671 3928/591(1) a) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE ©P.O.BOX 196300 ¢ANCHORAGE,ALASKA 99519-6300 ¢PHONE 907-563-7494 'TELEX:CHUGACH AHG (090)25 265 TELECOPIER: 907-564-0632 October 2,1986 Mr.Robert J.Orr Operations Superintendent Golden Valley Electric Association,Inc. P.O.Box 1249 Fairbanks,AK 99707 Dear Mr.Orr: Enclosed is a copy of the North American Electric Reliability Council Review Process which we would like to utilize in evaluating our operating procedures. Since we are all in the same business and interconnected in one fashion or another,I would like you to consider joining us in going through the review process.If you are interested,please give me a call,and we will hold off submitting our data until you can prepare yours.I would anticipate a coordinated submission and review. Sincerely, cS.NU. Eugene N.Bjornstad Director,Production ENB/ckb :naerc Enclosure O Bill Sheffield,Governor '\ Alaska Power Authority State of Alaska October 21,1986 Mr.Mike Ridge Department of Administration Division of Telecommunications 5900 E.Tudor Road Anchorage,Alaska 99507-1296 Subject:Alaska Intertie Dear Mike: A number of outstanding issues remain concerning DIVCOM support fortheprojectsubjectabove.These are: (1)VHF repeater at Reindeer Hill -This requires your sub- mission to the Power Authority of a completed RSA for processing. (2)Voice grade circuit between dispatch centers of Golden Valley Electric Association,Chugach Electric Association and Municipal Light &Power -this requires you to pro- ceed with installation and testing of circuit. (3)Data grade circuit between Teeland and Goldhill sub- stations for use by University of Alaska-Fairbanks -this is required to support the monitoring of neutral current flows in the Intertie -this is a formal request to pro- vide this channel and all necessary telemetry equipment for this purpose technical contact at UAF is Robert P. Merritt -UAF has an existing contract with APA to pro- vide this monitoring capability as a part of state spon- sored research in this area. (4)Data grade circuit between dispatch centers of Chugach Electric and Golden Valley Electric Association --see attached. Please provide me with a timely update concerning your activities in these areas.The Intertie Operating Committee has requested that I invite you to attend the next meeting of the Committee to discuss the activities of your agency in these areas.The meeting 6615/659 PO.Box 190869 701 EastTudorRoad Anchorage,Alaska 99519-0869 =(907)561-7877 Mr.Mike Ridge October 21,1986 Page 2 will be held Wednesday,November 12,1986 at 9:00 a.m.at Chugach Electric Association,5601 Minnesota Drive.I hope that you can attend.Thank you. Sincerely, on L.Beek Harry L.Beck,P.E. Operations Engineer HLB/fsm Enclosure as stated cc:Dave Eberle,Alaska Power Authority DC TIVY9d®i.4¥4WO99TELaUNO'SIAIOD 22 .d @2 100 98. O swiWayV 6615/659 it 1d3ja RECORD Cory 4) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE ©P.O.BOX 196300 e ANCHORAGE,ALASKA 99519-6300 *PHONE 907-563-74944TELEX:CHUGACH AHG (080)25 265 TELECOPIER: 907-564-0632 October 8,1986 RECEIVED AY Alaska Power Authority ALASKA Oe a P.O.Box 190869 Anchorage,AK 99519-0869 '86 OCT 10 P3:32 Attn:Mr.David Eberly Subject:Acceptance Testing of APA Intertie Data Link Dear Dave: Preliminary tests of CEA's APA Data Link were successfully completed September 12,1986.Chugach will start final accep- tance tests during the week of November 3-7.You are invited to send a representative to observe these tests and also review the as-built drawings of the CEA SCADA system with the additional hardware installed for the data link.. I would also like to remind you that as of this date we do not have the circuit to Golden Valley Electric Association required for our data link.Alaska Department of Telecommunications provided the modems,but the circuit has not been established. We would like to have the circuit activated prior to the start of the final acceptance tests. Sincerely, Vance Cordell COnPES-CNOcKCEBicyManager,Electronics ACTION:Cope vc/biy Knan/Beck |towns sVC:1008b |i =$ELIGRnS cc:Robert Day,ML&P |iRobertOrr,GVEA | _/AREAL !Harry PLEASE CorrowaArE NEES AY Atti 7O 4errvare THE GVEA Cikew4T, P39 RESrIaWO TO Vanecl RECADING Desscf 10 fATTiND AcearTaece TESTING,. Bill Sheffield,Governor :ArNADMaIee : Alaska Power Authority 86 OT 24 PDA State of Alaska October 23,1986 DIVIS'ON NF TELECOMM 9'sith, Mr.Mike Ridge Department of Administration Division of Telecommunications 5900 E.Tudor Road Anchorage,Alaska 99507-1296 Subject:Alaska Intertie Dear Mike: The enclosed letter from Chugach Electric Association requests that the Power Authority,in concert with Division of Telecommunica- tions,provide them with two communications circuits between the Douglas and Teeland substations.These circuits would be used to support Alaska Intertie operations and would serve to improve the reliability of power transfer over the Intertie and to the Railbelt load centers as well.I would like you to include this request for DIVCOM support on Intertie related communications requirements to that submitted in my letter to you of October 21,1986. With the number of Intertie communications requests for service growing it might be necessary for you and I to meet to discuss these items and their expected dates of completion.For additional information,please contact me at 261-7269.Thank you. Sincerely, [..Bech-_ Harry L.Beck,P.E. Operations Engineer Enclosure as stated. cc:Dave Eberle,Alaska Power Authority 6670/652 PO.Box 190869 =704 EastTuderRoad Anchorage,Alaska 99519-0869 (907)561-7877 RECORD Copy FILE NO a) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE ©P.O.BOX 196300 e ANCHORAGE,ALASKA 99519-6300 *PHONE 907-563-7494TELEX:CHUGACH AHG (090)25 265 TELECOPIER: 907-564-0632 October 15,1986 RECEIVED EYALASKA&"*.: Mr.David Eberly Alaska Power Authority . P.O.Box 190869 '6 OCT 20 P3:05 Anchorage,AK 99519-0869 Subject:SCADA Communications for Douglas TRU Dear David: CEA plans to install a RTU at Douglas Substation early in 1987 to provide a metering point for Tie Line Bias.To support the RTU, CEA needs two channels (1-voice and l-data)from Douglas to Teeland Substation.From Teeland the two circuits can be routed back to our SCADA Central Processors via the CEA microwave O system.Please approach the State of Alaska Division of Telecommunica- tions to determine if they will provide the two channels between Douglas and Teeland Substations.Prior to further planning,we need to be sure that the communications channels can be made available. If you need additional information or would like to discuss this requirement further,contact me at 564-0711. Sincerely, Jone CordellVanceCordell |OU wie welaiice DISTAI BUTI.Manager,Electronics RTiON:|COPRNES: vc/bjy Knan/Beye |EBare®. vC:1015a ae |evans cc:James Hall,MEA |ploprtss John Cooley,ML&P || |Bée2at |hAer7 |e Due Dats:} PrieAsé covepiwart ferwiey CéA x Divbie . RESfana re CEA AS Arredtetare Dave Bill Sheffield,Governor '\ Alaska Power Authority State of Alaska October 31,1986 Mr.John Cooley,Chairman Alaska Intertie Operating Committee c/o Municipal Light &Power 1200 E.First Avenue Anchorage,Alaska 99501 Subject:Intertie Scheduled Reserves Dear Mr.Cooley: The Alaska Power Authority has completed a thorough review of the Alaska'Intertie Agreement (AIA)in regards the subject issue at the request of the Operating Committee.We have found no provision of the Agreement that would prohibit the consideration of transactions for scheduling reserves as a billable usage of the Intertie.To the contrary,the presence of a schedule for reserves during operation of the Intertie may preclude some other desired transactions (e.g.power transport on the Intertie resulting in exceeding the capability of the Intertie should the reserves be required by the purchasing utility).Scheduled reserves are no less a use of the Intertie and therefore should be subject to compensation in the same manner as energy purchases. From Section 8.4.3 of the AIA,the scheduled use of the Intertie shall be the product of the scheduled transfer and the number of hours the schedule was in effect.It appears that this section of the Agreement adequately and correctly addresses the means to be employed to recover the costs of operation associated with this use of the Intertie. fiLM.Robert D.Heath ; Executive Director HB/RDH/se cc:Ed Morris,Alaska Power Authority,Anchorage Harry Beck,Alaska Power Authority,Anchorage Intertie Operating Committee 6750/652 PO.Box 190869 704 East Tudor Road Anchorage,Alaska 99519-0869 (907)561-7877 O OP ALASKA INTERTIE ERATING COMMITTEE DESIGNATED REPRESENTATIVES AND ALTERNATES PARTICIPANT REPRESENTATIVE ALTERNATE GVEA Bob Orr GVEA Marvin Riddle CEA Tom Lovas CEA Ray Duncan ML&P John Cooley ML&P Mike Massin FMUS Larry Colp FMUS Alan Martin APA Ed Morris APA Harry Beck AEG&T Sam Mathews AEG&T Ken Ritchey Effective December 1986 6899/661 PHONE NUMBER 452-1511 452-1151 564-0742 564-0789 263-5222 263-5450 456-5168 452-7109 261-7214 261-7269 235-8167 745-3231 Dispatch Scheduling Subcommittee Minutes Meeting was held at AMLP in Anchorage on October 8,1986 at 9:00 A.M.Those present: Dave Borden HEA Sam Matthews HEA John Cooley AMLP Ray Duncan CEA Doug Hall AMLP Ernie Jamieson MEA Jim Hall .MEA Bob Lund MEAery=«GVEA The meeting was called to order by the Chairman,Marvin Riddle. Marvin stated the subcommittee's direction from the Operating Committee was to;1)determine a method of accounting for,and reporting of,operating and spinning reserves per the Intertie agreement and;2)to develop a railbelt interconnect restoration philosophy and policy to be used during major system outages. Discussion followed on different philosophies of how the system would best be restored. Each utility should look at minimum generation requirements they would need before attempting to restore major transmission circuits, including the Alaska Intertie. It appears there should be some review of time-out settings and windows presently used on major Intertie breakers'used for synchronization. MEA requested we test carrying a portion of Teeland load from the Fairbanks area without Teeland SVS and re-starting Teeland SVS against Fairbanks.This test is scheduled to be performed on October 16,1986 at 0700 hours. Reserve accounting and _reporting:after much discussion,thesubcommitteeagreedonthefollowingcoursesofaction. 1.Each generating utility must keep accurate records of this on-line capacity vs.loadings. 2.Each utility would provide this information to its respective Control Area Operator (Northern &Southern controllers). 3.The Operators (Northern &Southern)would be responsible to attempt to define deficiencies by the establishment of a_test hour once each week. Page 2 This test hour would be determined by the system peak load hour. This hour would be checked to determine if proper reserves are being met.The week would run from Sunday to Saturday. The Dispatchers want to try some test weeks and recording of the results before recommending this approach to the Operating Committee. DISPATCH SCHEDULING SUBCOMMITTEE Minutes Meeting was held at CEA in Anchorage on November 6,1986 at 9:00 a.m.Those present: Marvin Riddle GVEA Doug Hall AMLP Gordon CEA The meeting was called to order by the Chairman,Marvin Riddle. Marvin stated our charge was to develop Restoration Philosophy. Discussion followed on how to achieve this. l.Formally request status of telephone link to CEA through AMLP to GVEA.This is absolutely essential to develop any sort of meaningful restoration procedure. 2.Identify a dedicated dispatcher at each of the utilities that would be responsible to restore the Alaska Intertie and interconnected system (CEA,AMLP,GVEA).This would be the Senior Dispatcher on shift.(CEA Dispatcher will coordinate directly with AEGT to restore their loads and coordinate their generation sources.) 3.The Dispatch Scheduling Subcommittee has agreed that they will restore all interconnects and interties at the earliest possible time.This time is dependent upon generation availability and system stability. The Subcommittee tried a test hour approach for the test periods since the last subcommittee meeting.It appears this is the best approach to policing the required reserves.Attached are examples for the Operating Committee to review. The Subcommittee unanimously recommends this method of accounting for reserves. Li Oct 29,86 09:24.2762961 P.02/02Ottemy |23-208conQnneTSeerTrSPIN Require ment 4 Acta ey |OB 9.1CerF mr -24 ©47 oulm&IQ <4pttin7BiFsTeedaee ele,PP Oy ee a pet rr re fog Pe a 4Der icuney a re | oo NONE =-|Nyeeesfpecm ee aweee O / PURPOSE: SYNOPSIS: TESTING ON INTERTIE October 16,1986 Using the intertie,demonstrate the ability of GVEA to provide a small block of power to MEA substa- tions served from the Teeland Bus with the Teeland SVS in and out of service.(See attached tables for values.) Eklutna BKR 362 was closed,Teeland BKR 1110 was opened.Cea then opened Teeland 230 KV BKRs 4410 and 4610 transferring approximately 7 MW of load to GVEA.GVEA then lowered the Healy Bus voltage and ML&P lowered the Teeland Bus voltage so as to minimize the loading on the Teeland SVS prior toremovingitfromservice.With 2.9 MV on the SVS,|a controlled shutdown of the SVS was attempted. Three attempts were made for a controlled shutdown, then an Emergency Stop was used to take the SVS off line.After readings were taken the SVS was suc- cessfully started and put on line.Cea made several attempts to remotely syne and close 230 KV BKRs 4410 and 4610.Unable to sync and close those breakers,McKenzie 230 KV Breakers 4410 and 4420 were opened and Teeland BKRs 4410 and 4610 were Closed.Several attempts were made to sync and close at McKenzie.Teeland BKRs 4410 and 4610 were then opened and McKenzie BKRs 4410 and 4420 closed. Teeland BKR 4410 was synced and closed locally. BKR 4610 was then closed.Teeland BKR 1110 was then closed and Eklutna 362 opened,restoring the systems to normal. CONCLUSIONS: The Teeland Bus can be energized from the north using 5 to 10 MW''s of load to reduce the voltage rise and thus allow the Teeland SVS to be restarted for voltage regulation. The 230 KV McKenzie Teeland line can be charged from Teeland with the SVS on. PROBLEMS REQUIRING RESOLUTION: 1)Control stop on Teeland SVS must be fixed. 2)Adjust relaying to allow syncronizing atTeeland230orMcKenzie230breakers. O INTERTIE TESTING ON THURSDAY OCTOBER 16,1986 McKenzie Teeland Teeland Teeland 230 McKenzie Douglas'Healy Healy 138 Bus svs 115 KV Bus Open End Bus Bus Bus SVS Time Voltage MV Voltage Voltage Voltage Voltage Voltage MV Prior to Test 0706 139.5 14.9 in 116.4 230.9 231.1 142.3 141 8 in 7 MW on 0725 145.7 3.6 in 117.8 232.3 233.3 147.2 136.1 22.6 in North w/SVS on 7 MW on 0740 147.8 0 117.8 233.3 226.4 147.2 135 27 in North w/SVS off 7 MW on 0745 149.8 -9 in 121.9 232.7 235.1 150.3 139 24 in North w/SVS Restarted in =inducthveSVSon[off =Teeland SVS m MAP a .O O Day &ws ©man ; 0100 4200 9300 0400 0500 0600 0700 0800 0900 1000 1100 1200 1300 1400 1500 1500 1700,1800 1900 XO 2100 2200 2308 2400P.01/03bi 5 ox |a¢Is [27 135°197 |34 [ae [or se laslas [3s [ar]3e]38]471s]33]73]S47 [33Fer:71. 2. 3. a 4 Xt 5.'AWE AP I>(975913969 P24)[3757]249 [3 PAY SAW ABZAY ve by Ee '.$ater be Bhs 2K [929 124 Ber 80 [ei 854113542185m|BFF |2900 52|854 |9%12 aIpibTys 2.41 WB et Was Wet [15Vg Wat |B V4 ValseWe |254 eae |ai7e,Peavec pe "t.rn ae APALAs acneBSAL iBACABARAE AG ARO ARAVA ae aed oe Lor lye lez 162167 Be Leb |70]131 Tt]68 |6S]6%]624 O35 |63 |oo]53 59 GoleSs|bs fly Na!ohadGo>RN)NFwyxwwANNosA\SMeWS.me,=aaeNov10,8601:182762961werain=\eatNea,vineoy- A@.ems'.NAX3}"amA%.-\&Ssecme) yr O Qn,MOAI 0100 0200 0300 0800 0500 0600 0700 0600 0900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 JO0!A we [-3 |-/|-)|---|3 |¢[sx |v pr ps [vy pe Le dt fa NU6 lat WSPs 13montPatLissoy&fe SSI lst s8e see Fy,Wr Be Sy se S&Ais.AA A Ey Sh [STH ;301729 ENE Ko %5 AZ Soi,SKE Se A §V 1h AE remoen HAS,SIS,WK ISK SZ SS |S Se iS SA Ke ISA VS LS "EA 'SO |S6 \WS4 'ith ,ISK LK iH |3 [1%SL ISZ PS ISG [5 [SoS SG |154 Z\9,t t '$6 1S 'may By SARA AGAR py y >Ae Plc [>2h (3 2 3 Kj :hens KE wel Ls Ze %o YA 2g "A |!2 4 Za a el 2!¥20 Z ](A Ks El :ve seo g>|acl se|361 ae]36]371 92 [9¢|ve [92 [st 15a |So [ye |123 69 feu dng 14 13 |3d [seme |67]701 vil zy]ar 6?62 1 eF 1?Jeo fos [ee |oe Jes 16?79 ICO.G2IbI gi leu ¢7 Eta ?.' 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Oe es weve dbumsoaehsmmnane s-... oe i 8 if 8 i -'iw oun:oo vevt GeV «ef ed Ol Ot OF tS Qa 15)406?1TKST -§2232!21501 DelO8!2.066)2.044)2.0451 2,023)2OBMtt 4st 384FFewnn---Ee ee eee ee Yt ee ee er --_- Z9LZ 6E:60 98°60 AON to°d T96 Nov 09,86 17:38 2762961 -- ve, \e P -°-_- HISTORICAL TIFS ANN HTan Loan,16200 09-KOV-B4 VESFRTCHERS GO LANGCTY /ARP Frm mm mom twee meg opener gewoon +Lowe em bmw monesomewendtoanwongconcent '1 9900 '1000 '$100 1 1700 1!236060 |1460 '1800 |1400 #!Hay |PREV !pe ceenn ene fees be eee ndewen cn pecnemabmenmempewmannpennemegpenne.4b:' (TIES:!'t )]$§'tt 1 ' 14393N {6.4!4.4!a3 3.7!3.7!ay 2 |Az!4a.c88 e471 6\ 1230 '1.71 563!4.2!3.08 4.71 Ze?t 3.0!4.31)1231 1356! IROUGLASIM 10.016 10.016 1O0,0IM 10,.01M 10.0'M 10,016 160.01M 10.011 t 0! 1UNY 830)0,9!9-0!-0.,01 0.0)9.0!0,0!-0.0)0.0t!"91 "QO! ee eee ee cee fenem ee dawwanaduonany fewsec an)means ger cwwed hnmennngivn eond INET INT!HWL.98 =OoLE -3.51 +1.08 1661 -207!-2.9)$.80)-791 -7Bt {SCHED |!8.0!8.0!8-9!8.0!8.0?8.0!O.0t 14.088 vor Ltée! IINADVT § O.91 -8.1!1 -10,8!=-9.81 <9.69 30,71 10.8)H40,918 dD!a Dadt tacc Inpi O.0!0,0!0.01 6.6!6.01 0.01 0.6!0.01!'! ISON REVI Feed!S706!UL-4'BO.DZ!41:41 B3.4b G7.,48 B87.08f 1390)1715! tAMB THP!28.3)29.0!279.9!269!BH,4!BI-Si 36.01 FA.Fil 1 $ rn OP CP.So Po ee 2.cette 6 ee |ee | 1MEAt (!!$'1 t ){!'' HTEELAND!33.2!BSe2t 34,0)BS.7'J.2t ARB!Bs.b!33,9!!so!935! 1EKL ACTIN 72.0'°M 27.0'M 22.018 22,.01M 22.01%22.016 22-0!1M 30.011 199!4ahal 145M bw AE ALAN MBSE HBOS!HK BePL KH Be7l Hae Dd wT!421 6) (FKL 34216 06.016 O.0IM O-.OIM O.01K O,0!M O,0!IM O.OIMN Olt!:vi IMOUGLASS 10,01 10.07 ©20.08 -101501 +£0.60)-20.08 -10.0f -10.0!!+1604 +240! 'MFA Ln tf 4a?.it 46.9F 3004!B20!uOed!4¥.8)a¥.3!4au.uil 44g)rossiSscecoceeSoeeeleooSe©er Pome fF tale i i t '!!'i 11 f \ (PKI MLO IM @8.01M @-B.0I1M -W.0IM -8,01M -G.0I1M -8.016 "8.01M 146.01)"80! 168!(MIP A IH 6,.60°H O.01KH 8.016 6.016 G.0tNH O.61M O-.016 6.01!ot qi (CEA MSCIM 6,016 O.OIM 0.0!O.0°6 09.0'M 0.016%9.016 O.01F!oO!oO! IMLP-OY 16 O<.0IM 9,016 0.01%O.601M 6.0168 6.6016 O.OIM O,0!!Ot QO} IMLF SCHIM 8.01M 8-0'M -B,OIM -BeOIM -8.01%-G@.01M -8.09M-16,01)"BO 6deel{MEP ACT! -O.it 0.91 =765!=8,7'w-M.4t -7.31 7-11 o15.8I!"681! 1621 '1 ]!f '5 !t ie)'t (MLP INDI 0011 1.9!OoS!"O57!-6.41 0.7!0.9!Oo2!!-i!é! fMLP Acc!0.0!O.Ot 0,08 0.6!9.0)0,0!0.0!6.0r!!' donee ee fewer aco bh mamma bosaae oy ee oc wnwwe fas wawmogeoa..=.;q eee ee a@¢ JeKL GWENT 't !5 !''tt {! (NLP SCHIM A,OIM ROTM ALOIM RLCOIM MOIR meOiR GeGIH 146.8!co!¢29' IMEA GCI 0.0!0.01 0-91 9.64 9.903 0.0 9:9)?Oroll Ol ot 1CEA VCMIM 14.01M 14601M 24.01 14,016 14.016 L4.01M 14,.01M THO!tive 23H) |!!]t 4 {]!tt !i] 1EKL SCHI 22-04 22,08 22.01 22,01 22.01 22.01 22.0%39.01!199!406! (Test $2.0@a!2.2232!2.276!2.3041 2.379!2.3221 2.316!2.219122.801353.460! 0 tte Se ee er ere ee et ee oe Ol Nov 09,86 17:39 2762961 UISTORICAL GENERATION SUMMARY P, 9999999999999999999999Pig] 14300 O9-NNU-RA DISPATCHER?DE LANCEY /ORD *LOe Sete ten Soe Co te te ee Pere tt Pte ttt et te 2 ee) i $9900 1 9060 '1100 |!1200 |1400 1 1400 1 2500 1 1608 ft!nAY ¢@REU t $ro--°bmn.of ee mmm dren cerfoenesonhecensefovassadhwmn...sfres ard $..c eo |cme we + (BEL 2 0 Abe Ft ASST!UH PE ASLEE Abe St 6FGeSt ELLE OI.OEt 144!7a9! !2!4.5!14,8!(5.49 25.48 6.5 15.647 AaB fh LF.at!134)2635t $3!Q.9!O.0!0.01 0.0!0.Q!o.0!6.0!0,01!0}Oo! t 4!Sa!eet Me ot 3.3!5.3!$.41 S.4t S.8t!B44!@4! '3)G.0 0.01 0.9!0.0 Q.Q?6.4!0.0}OOF or »oO} (GF Ghat AFoi?weed!42,91 4%.%!'462.31 62.8!62.451 97GB 43425i7$$b7Febt BA eot S74t C7641 G7At bbo9!BFL29 ATT!AUEes s0se !@ !SS.1!3O.2'80.29 50.0!4¥.8!49.61 497,81 49,88!7781 612061 1toT 1 ZOD Bf 219.3)216.01 216.08 215.51 214.98 218.01 215.3)!3163!6917! 10A8 1 20084!2ed211 252761 2eTO4t 26321!2.323!2:916)2.2441!33!$3! [«7c empona-cafmnmaanfmantampurananegmmunanagumasanthumaswahawwvoruahpoenomwoate sent 'INT 43 1 0.01 9.0!0.0)6.0!0.0?6.0!6,90!O.4!!ot 9! '2!0.0!ud}o.dt 9.9!4,01 6.0)0.90!0,08!Qt 9! !3 0.0}0.Q)0.0!9.03 0.01 0.61 0.6)0.088 oj 0! itor 'o.0!Q,00 wedi 8.0!O.91 Q.01 0.0!0.0!OF at (C1.i!QO.8)2.31 4,3)3.4!2.9!1.8)3.3!1.99!wre ei! |2!0.3!24!4.2!3.73 2ett 3.0)1.81 Leal!17!65! 'TAT 4 o.4!4.91 a,%!7431 4,31 3.6!Soil 2eltl 34)126! {BL 11S 06.618 6.6/8 O.O0!8 9.9016 O.,0ty G-SIB G.518 8.01!go!at v 2!0.901 0,03 6.0!9,01 6.01 0.0!0.0)o.0t!1 O1 ot !33 0.0!0.0!6.0!0.0!0.9!Or0!0.0)0.01)14 4ai '4]0.0!9.0)3.6!7.2!Fett 7Ai'7.2}Foil sv!31! ToT '0.0!0.9!Sed!7.2)72t Fett 7.2t 7iitl 4i}79! |oe rer rene ee Per ene Se eS eee Cee ees errr err {SEN TOT!POZ.G!220.3!227.6!230.5!226.8 225.6)225.3!224.581 S24T!Saves DE ree ee or ef ee A.oe coe 2 oe eo Perero| IMAP 68 $M (O6OIM OLOIM 0.0'mM 0.0'M 0.016 O.016 O.0IM 0.011 0}QO! tEKL-MLP I 8.61 0.0!Po A.o}8.0!8.0}B.90!146.08!uo}160! {CRA"MLPIM 9.016 O101H OcOIM O:.01M O-01M O.0fM O.0°M G.011 0!oO} {COA-GV JIN 0.01M O.0'M O-.OFM O.OIM O.OIM 0.014 O.OIM 0.011 coe)6} {MLP-GV 1M 6.01tH 0.0!M 0.01M 6.0'M O01 O-OIM O.0IN 0,0!!a)oe {Loss 1M 6.01M 0-096 O401M O.01M 0.01M O,01M O.0!M O,0t8 Ol oO! Pomemmirem$e eens o [vce wwe fan emma}cm nven hewmen Pe wnnmahawccwe donna:oe ee Se efISCHRED§H.O)01 8.0 @.0f 8.0)M0!8.01 1660!aot 168! (INADYVT }"O.1!-1.91 0.8!0,25 0.4!0.78 OF!o,2tt i)ét SEKI-CEAt 14,04 14.0!14,01 2460!214.01 14:01 24,01 14,601!Ligt 238! ICKL-MEAIM O.01M 0.016 O,.0IN O-0!'M 201M 8.5164 O,OIM 0,01!QO!9! Seryereeeeee eee oe 4-ee re| oan 1 7927.9!242.61 293.6!255.01 254.6!252-8!248-41 244.211 3404!CG201 4 tooo 8 -$-"et fer ee ee,ee ee eee eer eT ee ee eo Nov 10,86 01:20 2762961 HISTORICAL TIES AND MISC LOAD 24206 09-NOV-864 DISPATCHER!DC LANCEY 7 ORN SeDeeeyOrem Ot Done So ee Dt ee re | i]1 3700 *1700 §'4900 +2000 t 2100 '2200 |2300 ¢|2400 11 DAY 1 FREY Oe Ce ee oe Pe Cee fort r Ser ee et eee ee TIES?6°$1 I '1 '(.,ef !' 1225N !10.21 O.%!7.9i 6.7%Go4!LOPE -8,h9 AZ.7E!Ch 4! 1930 '4.4!Fev!mal 7th en!2.91 Feat «83,48!179)136)IBUUGL MDI LOeStH 40,01 10.01 TH.0916 16,056 10.01%16.018 16.081 ot at UNV WSO)6.ct $.9!"9.0!a,ot 0.01 0.01 -0.61 Oeutt -0i St dv maene Cee Bt Bo ee ee ee ee eee S eee ere | IWET INT!6.6!6,91 8.31 5.0!BoPt 104!<Fe3)-160T0!"71!-76) 1SCHED !£4.01 {4.01 £6.61 16-0!$6.61 8.96!6.05 6.081 168'168!(ZNADVT 1 -F14F -1000F 10071 -10021 20028 <P eat -F,BI -20.385 -299!-2eal (ACC IND!0.0!9.0)0.01 0.01 0101 0.01 0.01 O.Otl !t {APN REVI 98.01 76.01 75.0!85.0F F720!797.01 79.01 86.01!42osol 79S tAMB TMP)3t,3t Ft.21 3o.B!FO.7'36.8!BO.M!BI-7t Traret t ! Oe ee OT So ee Corrs i wre cc Fm.reo ben anapoonesoguvacanua$bans ouanhbnesaene> (MPAt 't !!'']t tt '' {TERLAND!36.01 37ed!Ford!34.9)33.80 3O.Bl 77-At 24.81)G7at 935l TERE ALTIM 56.014 3O.01M 30,01 JO.O1M 30,01M 22,016 7.0IM 6.011 37AY anat 1225N t 210.21--Goll «707f -B.71 -%e4!©10.7!Hod!13.78!9!"4! (EKL J62IM 060M O.0'M O.90fM O.016 O,0IM OcO1M O.OIM O.0!!8 Qe!Q! IPOUDLAS! 10101 -80.01 -40.0f -10.01 16.0!10,0! 10.01 -30.011 =2901 -2491 (MEA LR 1 Shedd Bod!SAZt HIG!HWBt BP7!SALe2t BA,4t!THPH!1095 |rf.oe oe es enc Sri ne Cor onion ©2 finer:ferre nr none y aur '''t |iT t tt 't PERL MME EMP Ae DIM TA OEM TALQIMKTALOIM=14.0IM @R.OTM O60'M O.0!' 848'<14N1 HELP O IM O6OtTM OcOtM G.O0IM G.OIM O,01M O.01M O-.OIM 0,911 Ol Ot ICCA NSCIM O:.096 0,096 O,00M O-.CIM O,O0IM O:1.OCIM O,OIM O,08)1 6!oO! tMEPLBY 16 0-014 0.016 O.616 0.016 O.0IM O-.OIM G.iOIM O.O!!9)at IME GOHEM*TALOTRHKLASIRESeSIMaeThsGINA.OIM -8.01M O.O9M O01!-248! t6eH!(MLP ACTH 1606!-16.08 -2£5.3!-35.81 25.91 -8.4' 0.5!Oostl LaHvt whee!!'!!'t 't 'tt ' IMLP IND!-6,.6!0.01 0.7!0.7!Of! -O6.41 6.53 O.si!=1}é! 'MEP ace!6.0)0.90!0.0!0-0!0.91 9.01 0.0)O.01!}i] PePanepe!Sn aren cece kteretn ce Daron Sonn tooo:©trop ee! 'FKL GFN!'4 ''''1 it '! t(mebir STHIH 216.609 16.086 146,01 14.016 16,018 O.OtM O.OIM 6.011 160!14661 {MEA BCHI 0.9!0-0!Q.0!0-0!99!0.01 0-0!9.0/5 o!9° 'CEA ROHIM 14.096 £4.01 14,016 J4.01M 14.01 L401 7,0tM 0.01!2161 236! 't '!1 1 i]'t |'' iEKE BEHI 3O,-Ut 39,01 39.01 30.01 30.0!22.01 7-0!0.0/1 378!496! 'TreT 'Pe aon!2.3!7.5!2.38 2.2!2owl aeatt 314!@S4!CO Poe.Pe Pe Oe ee ee ee ee |ee er See| P.02/02 w Nov 10,86 01:20 2762961 P.03/03 Oct 10,86 00:329999999999I9 FT 9999NNIFHIHIYIIIIII YD BOL WESTORICAL GENERATION SUMMARY 24700 09--NUV-BS j -” DISPATCHER?NE LANCEY /ORD .2ine tee foeLtr a4 ce eonenfocwwans}concen faoac ase huseccafoaenvag$don vnaafacecoe 4 !{1700 1 AGO |1900 §2008 |2100 !2200 H 23600 |2400 I!DAY !PREV !” Freewe oe Soren eet oD ee '|ttn Doe2 te +(BEL 3 |214.80 284.58 14.51 214.51 14:67 24:58 14699 32.411 rr 2a97t !21 18.8t {9.21 £4.98 25638 135.481 148.2!12.81 S.70)244!263! Hy a 4.05 2.Qt 0.01 9.Q!0.0!0.0)6.6!O.O0r!)oO!0! !41 8.3!§.3!$.3)8.31 Se3t 8.31 5.3)Jolt 1231!O41 (§!0.01 6.6!0.6}0.6!4.4!6.6!6.608 6.G8'Ci]ge° {6 t 42-5t 62591 O2ed!O4eBi 6205!O2.3!62.6!62.68)1488!15478 '70 BPo2t 69121 OF eat Ard O70TE GF 1St S764t G7.4bE ISFSI Bday!_ t Bl 49.971 49.99 49.91 49.91 49.41 44,91 5SQO.0'8A,7!1'FI7RE 12061 TOT PAGAL BW4AL QWHoTS!BA4.Ft 214,H!'AIALAt 717A!200.4!!4069)sal!'QAK 19.233!2.248)2.288!2.2841 2.2558 2.23231 212491 2.22001 Sst Ss! cd we eg.ter wee pemmmomparnwwe hemes enfasmansahusnanndgunawareedfmeouncogonuwuns|}” INT 1!0.0!0.6!0.6!6.0!5.0!6.61 4.61 O.08F 6)ot '7)0.0!a.0!0.0'0.0!0.03 6.0!0.0!OO}ot Qo! 'a os 2 er es 2 2 ee 2 2 a 2 a)91 {Tar-.!0.0!OeO!0,0!0.0!0,0)0.0}O.0!O.Or?'ae Qo! 'CL.|1.0!7.0!7.58 Pol 1.0!eit Qa!0.911 37!61! '2)2.01 3.4!2.6!Zell 1.11 OP!6.0!OrObt 271 43) TOT J 2.0t 10,.4t 10.191 %,3!Batt 2.61 6.271 O.68t 44}124! "(BL 2 1B.06018 O.08B G.OIS 0.018 0,018 0.016 0.013 O,0r1 0!ot i]2!6,06!6.91 0.0)0.01 0.6)6.0!6.61 0.o1?oO)or - '3 1.31 3.4!7.0)3.91 3.0)3.O}3.01 aOtt 243 4%) !4!7oi!7.0!7.Ail 7.1!Foil 1.21 0.61 O.0!t 7a)Sut ifu ;G.St dGcht AGeTi 30,531 10,11 4.23 3.90!2.9%!109!?7¥' C cette2Ccwmamahbaamawedauenaapumemanponenseendaennampaawunundwewwondfownsuad | 'GEN TOT!225.7!asa.9)234.8!970.3!277.0!220,01 216.01 203.41!80331 S222!aoeor(vere famemerge emmmaboassaadewovemgacanangnananndgumewnsfoanann} MEP @ 96 O.0'M O.9:1M 9.0'6 949096 6.019 0,016 O.4°N O.011 or ol tEKL-MEPt 16.0!{6004 14.0)14:84 14.0!€.0)0.01 o.O00!1681 1681 . CLA MLPIM O-OIM O,OIM @.01M 0:01M O,OIM O.OIM O.OIM 9.01!ot 9} (CQRA-UY 14°0.01K 0,016 0.016 G.O1M Q-01M 0,01M O.O1N 9-08?Ql oO} Mim GY oth 9.4¢m 6.41m A,AtM ALAIM AL4IK 6.616 6.0fK 0.0!!Oo}6! 'LOSB 1h 000!'M GeO OcOlM G.01M O.01M 0,016 O,0IM 0.011 ot 91 - Jone ace chew ence fan coe pen eens bane wee beeen bene nnn femeena gems mend banwmwed areeeed1GCUCD|16008 16.01 16601 16.601 1660!8.0!0,0!0.01!tout 168! TINADVY §©-0.6!8 6.0!0.71 0.2!O-11 "0.6!<-0.5!Q.3t!oe @ 6}1EKL-CoAt 24,01 24,08 214.0f $4.01 24.01 14.01 7e0t O-O01!8 2108 238!IEKLMEAIM O.OIM G.OIM OO.On O-.O1M O.01K GeO!O.01K 0,018 al oO!-,oteSo 2.Cs Pe Goo cee creed rm fmm an dgaemnemntpowmnwrgdumonaah'LOAN §63.21 2Qards HALT!27703!7AG.70 PARLL!232.01 208.91)SSS5!'Apodwnnnngencebbewmwefenmnmedaeemnnpaneaewdewenn$e n need eee +4 wo ceased O ANCHORAGE-FAIRBANKS INTERTIE RELIABILITY/CRITERIA SUBCOMMITTEE NOVEMBER 6,1986 9:00 AM University of Alaska Fairbanks,Duckering Building MEETING MINUTES Presents: John Marshall,Acting Chairman -Chugach Electric Assoc. Harry Beck -Alaska Power Authority John Aspnes -University of Alaska George Mulligan -University of Alaska John Huppert -Golden Valley Electric Laurie Oppel -University of Alaska Jon Richards -University of Alaska Brad Evans -Chugach Electric Association James Hall -AEG&T Steven Haagenson -Golden Valley Electric Moe Aslam -Anchorage Municipal Light &Power Larry Colp -Fairbanks Municipal Utility System Purpose 1.To review preliminary power flow base case and solicit recommendation from the utilities for other cases to be studied. 2.To discuss use of other software to run system studies. Mr.Mulligan presented the information used to perform the base case.This information is attached.Also presented were computer summaries and the results of the base case power flow. To facilitate an up-to-date power flow and stability analysis, the utilities have agreed to furnish the following items for 1986-87: 1.Each utility's peak load; 2.Scheduled interchange Anchorage to Fairbanks -also between each utility; 3.Generation dispatch schedule. The committee agreed that the following would be appropriate load flow and stability cases to be run by the University under the existing contract with the Intertie Operating Committee: O Meeting Minutes -2-November 6,1986 Power Flow: .Peak Load Base Case -40MW Anchorage to Fairbanks .7JOMW power transfer -Anchorage to Fairbanks °40MW power transfer -Fairbanks to Anchorage .Light load condition -(40%of peak)OMW transfer but Intertie energized 5.Light load condition -(40%of peak)20MW transfer, Anchorage to Fairbanks 6.Peak load base case and loss of Beluga 230-138kV transformer., 7.Peak load base case and loss of GVEA North Pole unit with BVEA Capacitor Bank on. 8.Peak load base case and loss of Teeland SVS. Stability Hy The following cases to be demonstrated using peak load base case: 1.3-phase fault with loss of either largest single unit at Beluga or AML&P Plant 2. 2.3-phase fault with loss of Beluga 230-138kV transformer.O 3.Thyristor failure on Teeland SVS unit (full capacitorinsertion)with 20MW transfer -Anchorage to Fairbanks (power flow case 5) 4.&5.Two (2)more cases to be determined at a later date. Stability cases are to be run to 10 seconds from fault inception or to demonstrated instability,whichever is less. Utilities are to review the data presented by Mr.Mulligan and transmit changes to him by phone no later than November 13th and by letter of confirmation by November 20th. Following the discussion of load flow and stability analysis,Dr. Aspnes presented information on the Electrocon utility softwareprogram.The University of Alaska,Fairbanks is investigating the feasibility of its use as opposed to continuing with EPRI software.A recommendation will be made to the committee no later than January 30,1987. The final item was a report by Dr.Aspnes on the status of the Geomagnetic project.Shunts are presently being installed atGoldhillfordataacquisitionundertheexistingcontractwith the Power Authority.A $16,000 change order has been approved O for installation of a communication channel for data transfer.The meeting adjourned at 1:45 p.m. JCM/tv2/502 SYSTEM LOAD DATA Company Load (MW) AMLP 165.6 CEA 206.2 FMUS 40.9 GVEA 113.2 HEA 63.8 MEA 89.3 SEWARD 4.0 TOTAL 683.0 AMLEP GVEA FMUS SEWARD (2) (3) NET NET NET NET 16 MW 40 MW 30 MW SALE 40 MW 66 MW 77 MW sale to MEA 4 MW sale to Seward SCHEDULED INTERCHANGE purchase from MEA (Eklutna) sale to CEA sale to GVEA 54 MW purchase from AML&P sale to HEA SALE =107 MW SALE SALE SALE SALE purchase from AML&P sale to FMUS -20 MW -10 MW -66 MW -61 MW -4 MW Note:(1) TIE LINE FLOWS To Fairbanks A 30 MW 70 MW To Kenai 58 MW from AML&P to CEA consists of a 40 MW sale from AML&P to CEA plus 18 MW to Fairbanks from AML&P through CEA. 95 MW from CEA to MEA consists of a 77 MW sale from CEA to MEA plus 18 MW from (1)above. 4 MW from MEA to AML&P consists of a 16 MW sale from MEA (Eklutna)to AML&P less 12 MW to Fairbanks. REQUIRED GENERATION Load +Losses +Net Interchange =Generation AMLE&P 165 1 54 220 CEA 206 15 107 328 FMUS 41 0 -10 31 GVEA 113 3 -20 96 HEA 64 2 -66 0 MEA 89 2 -61 30 SEWARD 4 0 -4 0 Summary Report Page No.1 SYSTEM SUMMARY MEGAVARSMEGAWETTSSYSTEMDATA 0.100.00 199.11, WATCHa .4aYiTE™"YT Summary Report.Page No.3 AML&P SUMMARY GENERATOR DATASUMMARYOF MYAR 2 3 4 9 ST IANtaurncTreIcen a a. C.C00Cermesese8 eeUVESerate a) >ts t > >¢ Ornere Om .@ eens>oOr Co Fave KT ”-!<xbooo OROOMORN- Ke wo COoNceMmeeneeeveFeOOneer, ec (NO AMAR vr a: Fa- m be ae we 7 COO 6 we-ayGabe>baUFbeTi he tr <tt ¢ aD i ieJ-wert ec¢ OREN Gatto 8greeedeeeGeLaeOa2 Summary Report Page No.5 CEA SUMMARY SENERATOR DATASUMMARYOF SLACK BUS au GOOOO0OOOm aw sueutuNncurumeal Dax AOOOQ0OOO he eeeesneeee CG Sererce «xO> AQao000roeaqgTeoOOe$$MNGOOO Mmm eeeeaneneoneb=ALOQiCuIPshKRiety HtZS PISOPeeeeet -i)_ COMMOOAICHE Se 200Oh0000amFwWeeeseeveseeeBSOPOAMAILRCG CRINKYS Fe eniwet bt tne peered 4fodieieeleeeateaedofoafO MAT PLANOLLMAROMMANMEeseoeeeenesSPAYANYOO ION MVAR COOIC COC: EaIeeeLomLannieLieDansaaeeeeZOAT PARANA OSORLRLRLT Time eirlto|eCc Cc: Foon VienLammSite ennai este eee ia INO Qh DIT AIC See 5 5 ev . e nd e ae or e coq ePNe copRE geeteeeMRKHIe 7 eA ARL TTR Le a gon ce Ps MondeeOh«orie Rood' on edRalGeelDeeSedoeee 7a DAT RPwWM AMA2¢pePeeereaeReR Cee STCaeeRarea) ron ew menFOb amamaoromCM Sst awe "Zz ©een eesFeowmweeimcooCS x OF NOMO u eee wza x eecae 2:cocie i Summary Report Page No.7 FMUS SUMMARY SUMMARY OF GENERATOR DATA MVAR TOTALSAREA OVEaietse?eer oe? D> Dowrermeoioy : sLteerer eta Summary Report Page No.9 GVEA SUMMARY GENERATOR DATASUMMARYOF UsusLd «o acwu [| w <tz bned"oe® 8ad - aQqoasJus DAOO «ao owner a<« -OOO - eecee Wat erOre «oO> AARQOQDBOATAACCOAM Awoh=-e 8&6ah tt INO8 EE EMNAK Fr Me - mtaedwl 1 -! oo 2ZZOQAOOD® re oo0o0r3zaMWeae ec WO+ S+WMMADDSFuwuah seme arn wes ofcereOOOMOKO SC AOACVNOOR aT ee teeee#8e DAT APIN OOM = we(WQOODOIOA ™mae eee wae es enn [oe od tet ANQWNTO AOOcMmMa Oo wWensenaneveFPP OOD OO <te- ano ue t= heod«a x teze 3: CO OF| THA & Cer MERARTLIDehebien aDARTeeeTer anim oa CEDve aeraigeyg puis erew wu Summary Report Page No.1]| HEA SUMMARY onooCROM@sestePeCcoageFase TOTALS DBNOANIDOac2oocnroo "Beservasvevee Foe ACKHhOO zc oOo 'oO te t oar turzr 7 Oo & cea ™ Vb ml ANbe sZtbetieregy nad BOAT xrays;ane OC Dea ately aseebalSa a Summary Report Page No.13 MEA SUMMARY GFNERATOR DATASUMMARYOF atayGdww"ctrNbUSondbaoaqNo>2zow oOo «io mM >s« oo lanl ee Wad m= aO> aoree "agoee reno "x b- aYe OO axe ™mesBannFie 8[ots4me Yr en C¢ oe => an b ocrDD zu ee ST PninnbodnaaedLoaramre > ee < wsreyo.°e oa fotya eae +& "27 mTcaNi TOTALSAREA onaoanwcesrwrTeeeeSree COUN znretDO DOADN res OCKh OM "™eee»ef esa Loe COOH 2 mo 7 -zmce:p>olok xre+C3 Oh mit. C9) fee FLUEee tieryENOCD Seettoe Pal doll CadCORoll fact bettersod atl Ener Ou, Summary Report Page No.15 SEWARD SUMMARY OwnodooacCOoOnanfC enee>orcooe= ONOONODOCe-COoooRPesaseeseeeeefw OiCco-rca TOTALSARCA nA TemeSFUY Str OESCoVeatsteasotoeDSDeSokDaloT) TO_GVEA PLL. ]2.4bb Ge 'hs HERNING SHAW O'NEAL LUCAS||F .paar o.artf 3 a 0.167 203 3,|{DOUGLAS -=FLoz sev =>[Ts |+=$F re os Tr |iANDERSON|1a 3-6 ostigs **"AIts ba 5 nly "fils10.994 WE:=.EAST 7 O.16GE 2 eeAlte2:2,stktwan 3 TEKMPNAL,LAZELLE"-Tse 1.001 eU 1.007 ev VtMcRAE;0.10 :31]he ANCHORAGE MUNICIPAL A 12 DQw LIGHT &POWER MATANUSKA ELECTRIC ed2_[liskv ASSOCIATION 34 o.VeS pvTOSETTLERSwoeaeevalteBAYSTATION2a--__-__--v.welteurl i SKY |af 230K _0.444 115ane STA Fxete.|po '6 aI ,4 |usey [1¥45 lif BRIGGS00%guzipPSvozoeSTA6te: _.: ;*.PIP EL,PARKS .REEDTEELAND138KVOAMAy=sri Ts 3 Hts rat cae (aaaf ei APAte]ae By t =aeineg2495allyyViisaoleeLag Fags tisKe ERLUTNA”STA 10 N.syed aa)»a t.o\G EY230KVSTA7p"oan 44 a0 |LITES gs §Fonal2407«sh,et ons -!=-\01.001 pv eo [<_|3s.)|S'S TAP %te Ee =.'Tet 6S tt &STA 16 STA 8 STA 15 S04)4 09th 0.14%O.W"s att u=PT.WORONZOF 34KV__02sePT.§oe)fev -spn ii e tole |of If etsMAC7hi:1 coe]2 [ef >on230KVTW2.0156 is I 23 -|_inp1an 6 PT."|e KV V.003 pu 1.et%puSlitMACV38KVINT'L lt t*1,tens --)wills GIRDWOOD*BELUGA me late als +Voz ev230KVTeispySso££|t_0.997 sty ANCHORAGE AREAele]1 :34.5KV UNIV.138KV TRANSMISSION SYSTEMit4rn138KV_oxtaceTowevSenerafeCHUGACHELECTRICASSOCIATIONHOPE|.ez gs oWMeV |LISKV q¢eMS ev oe ||. 25KV-s BERNICE LAKE . m sa |eas rd)7 lootev W :['SKV 44 T ry LSKY QUARTZ ait CREEK!4 ' ;bi [8 *SOLDOTNA CREEK sky0-19]69KV *Fresoro >69KV coKy b.ANI1 pe»|7 L.0t3¢Voetev fe8 ”°:Veo fons 2 iISKYvis44LovseviSLECTRIGoO?ou BEAVER|cASTLOF 69K SEWARDHOMERELEC i Thor arASSOCLATIONatt|eis sha ELECTRIC aes 4kv SYSTEMra[o.A%tMev |iT?¢Leregu!25KVHOMEraANCHORPT.FRITZ CREEK |7 oaa3 ev'-Jo-113eY ||'' |ee)+)hie S] GOLDEN VALLEY ELECTRIC ASSOCIATION 0-180evFOX MUSK_OXoe We cftts STEESE eo ?1 t -_-t 0.44 ev::|[*8 UAF UNIVERSITY AVE OA?fos,|"flera|bed tig o-0.187%ev PP rrave8i3)xt J>+>GOLDHELL 3%£.0 i i j_69KV O9KV "||"ZEHNDER &-\8 Sev FAIRBANKS NORTH POLE mat i MUNICIPAL |A JS?GUOLDHELE 'UTILITY a ayaH38kycinwaOO"SYST.g9KV -|-HAMILTON 13.8KVsUM '--O.993 ¢v o..4aS euAlePUMP ,Fs INT'L -p-o 409 ev |{s ponAIRPORT"| NENANA on ane a 69KV -T-0.236 eu'|[2 _|orn 138KV S008 pv ;Omer 'S.FALRB.\.eoey nile"le as\5 138KV "y4kVae elt?1eg?0.113 ¢y__HEALY rif |6Kv138KV2""r lyif]"Lit.Sree [oarster 2 jo:t theyea:"te |FT.WAIN. oan) UE 9 7 13a BEVteCANTWELL.PEGER RD.S.FAIRBANKS . o.Na Se bos ¥[>eee ad 7 ©O.WtS eV|-_ BADGER aysUli'|{ei FAIRBANKS AKEA \ KANSMESSION SYSTEM |oassgy 20 ro.98Nev EIELSONWa||"Oe o.184 6OKV ONMEOY ag 0.163 0U JARVIS CKparedayBROCKMANPisawa]$4 f ft,pst peeetlieg-+and >Seme.5 HIGHWAY md en Po Vee lo-8 0.440m1JOUN0.46 . PARK NEWBY es RD. CARNEY”-€v- November 5,1986 Mr.John Cooley,Chairman Alaska Intertie Operating Committee c/o Municipal Light and Power 1200 East First Avenue Anchorage,Alaska 99501 Subject:Alaska Intertfie FY88 Budget Dear Mr.Cooley: The Alaska Powar Authority has submitted to the Office of Management &Budget (0M8)a total Intertie FY88 budget amount of $1,769,266.This submission was made to satisfy requirements of the State's budgetary process.This figure was arrived at by adjusting the FY87 budget with an inflation factor.All categories with the exception of insurance were adjusted by an increase of 3 percent to arrive at their respective FY88 estimates.Insurance was adjusted by an increase of 10 percent to arrive at its expected FY88 budget amount.The total estimated FY83 budget,therefore,represents an expected increase over the FY87 budget amount of 3.23 percent. It was necessary to estimate the FY88 budget for OMB using inflation adjustments due to the lack of bhudqetary information from the Utility Participants.At this date,we have received only the estimated operat- ing budgets from Municipal Light &Power and the Intertie Operating Committes.It is aven more important that the Participants thoroughly consider and develop their estimated budgets in light of the budgetlimit(i.e.,the expected FY88 budget amount)that has been imposed by this submission to C13. I request that you,as Chairman of the Qperating Committee,direct the representatives of the Committee to submit to the Power Authority their astimated FY9S budaets no Tater than December 15,1986.Thank you. Sincerely, Huy bow ON Harry L.Beck,P.E. Operations Engineer HLB:tg ce:Ed Morris,Alaska Power Authority Julie Saarinen,Alaska Power Authority 6810/DD15/1 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,NOVEMBER 12,1986 BEGIN at 9:00 A.M. I,Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A. Dispatch/Scheduling Subcommittee B.Reliability Subcommittee C.Intertie Status Update (A.P.A.) D.Relaying Subcommittee IV.Visitor comments related to items on agenda V.Old Business VI.New Business A.Recess and work session B.Dispatcher/Scheduling C.Reliability D.Relaying Subcommittee E.Insurance F.,Reserve Billing G.Others VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Meeting location:Chugach Electric Association 5601 Minnesota Drive Anchorage,Alaska 99502 563-7494 3928/591(1) ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,SEPTEMBER 17,1986 (AT GOLDEN VALLEY ELECTRIC ASSOCIATION) Attendance: Jim Hall Alaska Electric &Generation Cooperative (AEG&T) Harry L.Beck Alaska Power Authority (APA) Ed Morris Alaska Power Authority (AP-)John S.Cooley Anchorage Municipal Light &Power (ML&P) Gordon L.Harter Chugach Electric Association (CEA) Larry Colp Fairbanks Municipal Utilities System (FMUS) Marvin Riddle Golden Valley Electric Association (GVEA) John Aspnes University of Alaska -Fairbanks (UAF) George Mulligan University of Alaska -Fairbanks The meeting was called to order by Chairman John Cooley at 9:15 a.m,in the Executive Conference Room at Golden Valley Electric Association. Minutes of the July 16,1986 meeting were distributed.Chairman John Cooley asked if there were any corrections or amendments that should be made to them.There were none.The Chairman motioned that the minutes be approved.The motion was seconded by Marvin Riddle and the motion was passed unanimously by those present. The agenda was then modified by striking the Reliability and Relaying Subcommittee reports and by inserting under New Business, "F,Reserves"and "G.Reports." Marvin Riddle reported that the Dispatch/Scheduling Subcommittee did not meet in the interval since the last meeting of the Opera- ting Committee.He stated that the reason for meeting was only to review any prepared results from the SVS testing.Results were not forthcoming and therefore the subcommittee did not meet.Ed MorrisstatedthatthereportfromGilbert/Commonwealth (G/C)on the testing had just been released and was being transmitted to the Participants.John Cooley stated that G/C wished that al]Partici- pants review and comment upon the study by September 30,1986. John Cooley then read the conclusions from the report.This section of the report,which summarizes the problems of the systems as identified during the testing,was then discussed by the Opera- ting Committee. Under APA Status Update,Ed Morris distributed copies of the APA draft memorandum on FY85 O&M trueup.He then distributed copies of the individual trueup billings to the respective Participants.Harry Beck noted that signature (final version)copies of the Maintenance Agreements had been distributed over a month ago but 6392/642 Alaska Intertie Operating Committee Meeting Minutes of September 17,1986 Page 2 were being held by the utilities pending a resolution to the spare parts issue.He stated that the Transmission Service Agreement was awaiting signature by the Executive Director of the Power Authori- ty:it would then be submitted to the General Manager of Matanuska Electric Association for signature.(Note:The agreement has gonetoMEAforexecutionpriortoPowerAuthorityexecution.} Harry Beck then discussed the grounding problems notes at Teeland, Goldhill and Healy substations.He indicated that G/C was in the process of studying the situation.He stated that the only damage reported at any of the sites was at Goldhill and that this involved a burn-through of a cable tray.Finally,he concluded that he expected that corrections to these problems would be identified by G/C and would be put into effect as part of the Intertie miscel- laneous construction to take place in Spring 1987.John Cooley asked if there was any further word from General Electric on the replacement of capacitor switches with vacuum breakers for the SVS. Harry Beck indicated that he had no knowledge of this installation. He indicated that he would follow up on this issue.Marvin Riddle asked that schedules for this installation be provided as soon as practicable. Chairman John Cooley reported that the Dispatch/Scheduling Subcom- mittee did not meet in the interval since the last meeting of the Operating Committee.He further indicated that this subcommittee should have met at the Chairman's direction to consider who has the responsibility for reviewing and changing Intertie relaying set- tings.Jim Hall stated that the subcommittee should look into the problem of the nuisance tripping of the Douglas to Teeland line section. Chairman John Cooley reported that the Operating Committee had received a copy of a letter from the Power Authority to MEA dated September 3,1986.This letter,he said,concerned storage of Intertie parts and materials at MEA's Talkeetna yard.Ed Morris then summarized the lease situation at Eklutna and the proposal from MEA to move Intertie parts and materials to Talkeetna.He concluded that MEA and APA would be negotiating this issue over the next few months. Chairman John Cooley also reported that the Operating Committee had received a letter from Dr.John Aspnes of UAF requesting al] participants to furnish UAF with their system data as required by the Data Base Management contract between UAF and the Operating Committee.He stated that it is also important that this data be accurate and timely as it will also be used in the Anchorage-KenaiTransmissionIntertieFeasibilityStudybeingdevelopedbythe Power Authority in concert with Railbelt utilities. There were visitors present at the meeting namely,Drs.John Aspnes and George Mulligan of UAF.John Aspnes presented a summary of the 6392/642 Alaska Intertie Operating Committee Meeting Minutes of September 17,1986 Page 3 Geomagnetically Induced Current (GIC)project presently being conducted for the Power Authority.He discussed the work that had been accomplished and that remaining to be completed.He stated that the remaining work essentially concerned the installation of shunts on the Teeland and Healy SVS transformers.Marvin Riddle suggested that UAF may have to install a shunt on the Healy transformer serving the generator since it is also connected in a grounded wye configuration. John Aspnes said that he could calculate the neutral currents in one transformer from measuring the currents in the other as long as the dc resistance of both transformers is known.Harry Beck stated that obtaining the dc resistances may not be possible and that UAF should obtain full price estimates for installing both shunts at Healy.He further indicated that the cost of installing an addi- tional shunt was probably minimal compared to the effort required in obtaining the dc resistances and then having additional uncer- tainty in the accuracies of the analyses.Finally,Harry Beck Suggested that UAF quickly obtain and provide him a full cost estimate for installing all 3 shunts. Chairman John Cooley then stated that at the last meeting of the Operating Committee,a question concerning the likelihood of experiencing GIC-related problems on the transmission system was raised.Marvin Riddle stated that to-date,GVEA has not experi- enced any problem,that they know of,on the Intertie related to GIC.Jim Hall recalled that at the prior meeting of the Operating Committee,there was a consensus to support the taking of the data for the GIC project,but that the analysis of the data may not be performed due to budget constraints.Harry Beck indicated that the Participants'feelings might change after the GIC equipment is installed and operating:i.e.the data obtained might change the feelings of all concerned.He stated that the members of the Operating committee need to develop a feeling for the magnitude of the problem and that at the present time,this is not possible as the equipment is not installed and operating.Ed Morris stated that the Railbelt Energy Committee may decide to investigate this issue when the Anchorage-Kenai Transmission Intertie Feasibility Study is performed, There was no Old Business. Under New Business,the Chugach Electric outage of August 30,1986, was discussed.As a consequence of the outage,Jim Hall indicated that MEA would like to test soon the ability of the Northern area system to carry Douglas at about 7-8 MW of Teeland load with theTeelandSVSon-line.Marvin Riddle then explained the GVEA philo- sophy of system recovery by keeping generation and transmission on-line at all costs.He said that restoring generation and transmission is GVEA's first priority and that restoring distri- bution is only used at first for voltage control. 6392/642 Alaska Intertie Operating Committee Meeting Minutes of September 17,1986 Page 4 Miscellaneous items were then discussed.Marvin Riddle asked when the dispatch centers would receive the long-awaited voice circuit to be provided by DIVCOM.Harry Beck indicated that he would check with Khan/DIVCOM,Marvin Riddle said that CEA and GVEA were now testing the data link.He stated that the scratch pad at least is working on the data link.Chairman John Cooley then suggested that the Operating Committee invite Mike Ridge from DIVCOM to attend the next meeting and provide an update on his agency's activities in regards to the Intertie. Chairman John Cooley indicated that the Dispatch/Scheduling Subcom- mittee should draft a system restoration procedure at their next meeting and should submit it for review at the following meeting of the Operating Committee.In addition,the subcommittee should develop a test plan to carry 7-8 MW at Teeland from the Northern area as discussed. Jim Hall then discussed the motor operated disconnect switch(138-253)at the Douglas substation serving the Douglas Teeland line.He said that MEA would like to be able to open and close this switch on the open-circuited line.He said that this would allow for restoring the normal system line-up following an outage without having to expose the Douglas load to an outage in order to operate the switch.Harry Beck indicated that the Power Authority and MEA were reviewing the problem and the solutions available. Under Relaying,Jim Hall said that the Operating Committee should encourage the Chairman of the Relaying Subcommittee to meet to consider those items discussed previously.Marvin Riddle felt that the subcommittee should be looking at methods to prevent cascading problems associated with the relaying itself.Gordon Harter said that the operators could agree on principles and practices for coordinating all of the interconnected system relaying through this subcommittee.Marvin Riddle then stressed that coordination has to be voluntary and would require mutual cooperation from all parties. Discussion then turned to Insurance.Ed Morris distributed copies of the documents "Alaska Intertie Insurance Options"and "Insurance Amendments."He discussed the proposed amendments to the Alaska Intertie Agreement relating to insurance.Ed Morris stated that it is important that the State and the Municipal utilities insurance programs satisfy the provisions of the revised Agreement.He then summarized the issues described in the paper on insurance options. Under Reserves,Chairman John Cooley stated that the figures shownintherecentreservereport(i.e.reserve deficiencies)from GVEA were incorrect.Marvin Riddle agreed stating that the figures were off by the Eklutna plant commitment.John Cooley stated that there was a one year grace period associated with not having to reimburse others for providing one's reserve deficiencies.Harry Beck stated that this year ends on April 30,1987,one year form onset of 6392/642 Alaska Intertie Operating Committee Meeting Minutes of September 17,1986 Page 5 commercial operation.He indicated that this is because the Agreement does not define any period of operation other then that of commercial operation:the Agreement is an Operating Agreement. Discussion continued on the subject of purchasing spinning re- serves. Under Reports,the need for a monthly management report was ex- pressed.Harry Beck requested that GVEA provide him with monthly metering summary reports from all of the Intertie substations for inclusion in the monthly management report.Marvin Riddle stated that he would provide them.It was agreed that ML&P and GVEA would reconcile the monthly energy transactions on the Intertie before providing them to the Power Authority.It was determined that bills to the Power Authority should be submitted to Harry Beck.It was determined that the present representatives of the utilities on the Operating Committee were the proper recipients of billings to the respective utilities.Harry Beck then summarized the results from the SVS testing conducted in July 1986.Finally,Marvin Riddle discussed the reasons why GVEA feels that scheduling re- serves on the Intertie is a legitimate billable expense for usage of the Intertie. At 2:05 p.m.,under formal Operating Committee action, Chairman John Cooley then directed the Alaska Power Authority to initiate the process to revise Section 17 of the Alaska Intertie Agreement in order to resolve the outstanding problems contained within it concerning self-insurance by the Participants. The Chairman then directed each representative to confer with his organization to establish their position on the issue of scheduled reserves as a billable usage of the Intertie.Each representative was advised by the Chairman that this issue is to be formally resolved at the next meeting of the Operating Committee. The Chairman then directed all representatives that have been contacted by UAF in regards the Data Base Management Project to complete their review of their respective system's data base and submit same to UAF by October 1,1986. The Chairman then directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to (1)Plan and conduct a test of the interconnected system's ability to carry 7-8 MW of Teeland load from the Northern area,(2)Develop and submit to the Operating Committee,restoration guidelines for the inter-connected system following system collapse,(3)Develop and submit to the Operating Committee,a format for spinning reserve report- ing. 6392/642 Alaska Intertie Operating Committee Meeting Minutes of September 17,1986 Page 6 The Chairman then directed the RELAYING SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to consider the GIC proposals from UAF should they become available to the Subcommittee. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERA- TING COMMITTEE WILL BE ON WEDNESDAY,NOVEMBER 12,1986,at 9:00 A.M.IN THE CONFERENCE ROOM AT CHUGACH ELECTRIC ASSOCIATION AT 5601 MINNESOTA DRIVE,ANCHORAGE,ALASKA. Larry Colp then moved for the meeting to adjourn.Marvin Riddle seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 2:25 p.m. Respectively submitted, i a Edwin L.Morris,Secretary Alaska Intertie Operating Committee Attachments: 1.November meeting agenda 2.Letter from Alaska Power Authority to Matanuska Electric Committee dated September 3,1986 3.Alaska Power Authority Discussion Paper,"Alaska Intertie Insurance Options,"dated September 11,1986 4.Alaska Power Authority Discussion Paper,"Insurance Amend- ments,"dated September 17,1986 5.Alaska Power Authority draft memorandum,"FY86 O&M Trueup," dated September 16,1986. HB/ELM/se 6392/642 aul Gretteala iN Alaska Power Authority State af Alaska September 3,1986 Mr.Ken Ritchey Matanuska Electric Association P.O.Box 2929 Palmer,Alaska 99645 Re:Proposed Intertie Storage Facility Letter of March 13,1986 to Howard Thacke Dear Ken: The Alaska Power Authority has completed a thorough review of the use of MEA property for intertie spare parts storage.In your letter,you proposed that the Power Authority contract with you to store Intertie equipment and materials at a site to be developed byyourutilitynearTalkeetna.This facility would consist of a permanent building situated on nine acres of cleared land,five of which would consist of a gravel pad.The storage building lease monthly cost would be $1,445 and the land lease monthly cost would be $1,783.The total lease charge to the Intertie Participants would therefore be $3,228 per month or $38,736 per year. Presently the Power Authority is storing Intertie materials at our Eklutna yard.We are presently renegotiating our lease with the Alaska Railroad for the Eklutna yard which will allow the Power Authority to continue to use the existing facilities for the next two years.The cost for the use of this site would be only the cost to install some additional fencing and the electricity charges for the existing lighting system.This six acre site is providedwithroadandrailroadaccess(railroad sliding on site).This lease constitutes the last lease that we are likely to be able to negotiate for the Eklutna yard.At the end of this period of time, a long term solution for storage of Intertie materials must be put into effect. It is our opinion that Eklutna should be retained as the storage Site for Intertie materials for the Southern side of the Intertie until such time as our lease expires.The costs associated with retaining this lease are considerably lower than those you presently propose.We will,as I've explained,must plan now for an eventual relocation of Intertie materials to another site and will meet the approval of the operating committee. 5947/634 PO Box 'S086C "S'ZastTudorRoad =Arcnorage AWaske 55'S CSae Soest 7877 Mr.Ken Ritchey September 3,1986 Page 2 The Power Authority is interested in discussing with you alternatives to the proposal you've presented.I would appreciate your contacting me to arrange a meeting with you in this regard. Thank you.- Sincerely, Hatin iL.Peale Harry L.Beck,P.E. Operations Engineer Enclosure as stated cc:Ed Morris,Alaska Power Authority 5947/634 DISCUSSION PAPER ALASKA POWER AUTHORITY September 11,1986 .Alaska Intertie Insurance Options During various Intertie Operating Committee meetings,the subject of the types and extent of insurance coverage available and purchased have been discussed.It was requested that furtherework be done by the State in investigating ways to reduce cost for present coverage and to add coverage for property damage to the transmission line,if available at reasonable cost. State risk management director has contacted foreign carriers to obtain rate quotes for the transmission property coverage and has not been successful to date.He is presently reviewing a program that was presented to the Power Authority on September 9th.I do not know if there is any proprietary information and present this only for your reaction to the concepts of the program. Proposal For Discussion Bonds with approximately 20 year maturity dates are sold for an amount to cover the largest probable loss.For the Intertie,this could be in the range of 5 to 20 million dollars.Security for the bonds is by the guarantee of payment by the participants benefiting from the program.The bonds are invested to provide a revenue stream for debt service (if earnings interest rates exceed borrowinginterestcosts).The remaining debt service costs are provided by a series of annual payments that we'll call insurance premiums. Premium payments are also used for restoring the bond proceeds if required and to pay normal annual claims.If premiums exceed costs for any year,that amount is invested in a self-insurance reserve. The self-insurance reserve is to be used to make the payments for major claims to its limit of its funds.The bond proceeds will be withdrawn for any additionally required amounts.If no major claims deplete the self-insurance reserve during the 20 years of bond life, the reserve is an equity to be returned to the participants. Caveat Upon Caveat This proposal has many of the obvious problems plus the usual problem of making it work if the State is involved.There may be many ways to structure the contracts required to ensure that the benefits of the retained funds will be the property of those assuming the current insurance risk.It is advanced here only for your reactions...so react. 6104/640(1) BOUND MAJOR PROCEEDS CLAIMS LoL ee | ¥INSURANCE EARNINGS PREMIUMS vw wv. DEBT ANNUAL SERVICE CLAIMS »SELF -INSURANCE RESERVE md RESIDUAL EQUITY DISCUSSION PAPER ALASKA INTERTIE OPERATING COMMITTEE Insurance Amendments September 17,1986 Members of the Intertie Operating Committee have requested that the Alaska Intertie Agreement be modified to reflect the lower limits approved by State Risk Management.In addition,there are continuing questions as to the adequacy of self-insurance programs and the need to remove perceived deficiencies. INSURANCE COVERAGE Article 17 insurance requirements were reduced form the ten million of coverage to five million on May 19,1986 by letter.This action will be completed by amending the agreement to incorporate the change when the self-insurance maximum has been reviened. PROOF OF INSURANCE COVERAGE Section 17.3.2 requires each Participant to provide evidence of insurance to the Operating Committee and the Authority.In discussions with State Risk Management Director Don Hitchcock,he requested that copies of the policies be submitted instead in order to review the coverage in detail.The Operating Committee can initiate the request if it wishes or the Authority can do so separately. What action does the Operating Committee wish to take on the request of copies of insurance policies? SELF-INSURANCE PROVISIONS In a letter to John Cooley on July 16th,I requested that ML&P revien their self-insurance coverage against the agreement as it exceeds the $250,000 maximum of Section 17.1.The ML&P question is still outstanding and needs to be resolved with a change in requirements or ML&P obtaining acceptable coverage. In the Operating Committee meeting of July 16th.the question of the self-insurance provisions applying to the Power Authority kas raised,The Authority question seems moot in regard to the concept of limiting liability to the State.Being the owner of the line, ' the filing of any claim will involve the State as a defendant except if the State files against one of the Participants.My understanding is that awards made against the State are not .limited.Any claim granted by the courts,not funded by insurance or containrd in a budget or appropiation is submitted to the legislature for funding.The Authority will entertain any provision that will limit its liability to less than its full assets. Further discussion on the ML&P issue will also be pertinent to the issue for the Authority.I propose that the original draft language specified "Utility Participant"and that the Authority was intended to be excluded from Article 17 provisions.Discussion by those directly in the negotiations will help resolve this issue or set the direction for the next step. DRAFT Ed Morris ;September 16,1986 Director/Operations &Engineering Harry Beck HE Alaska Intertie Operations Engineer FY86 O&M Trueup The table below summarizes the actual revenues and expenditures by type for the Alaska Intertie during FY86&: INTERTIE PROJECT FY86 EXPENDITURES CATEGORY CONTRACTOR/ORGANIZATION BUDGET!EXPENSE Operations Northern Area Controller (GVEA)$49,855 $49,855 Southern Area Controller (ML&P)$46,733 $46,733 Intertie Operating Committee $23,667 $0 Alaska Power Authority $28,057 $10,890 Maintenance Northern Area Contractor (GVEA)$46,829 §$0 Southern Area Contractor (AEG&T)$32,872 $i) Teeland Substation Contractor (CEA)$2,092 $0 Miscellaneous Transmission Service (MEA)$18:097 &rf] Communications (DIVCOM)$9:167 $0 "Repair &Replacement2 $165667 $0 Insurance $11:;474 §$9,755 TOTAL $285,510 $117;233 TOTAL EXPENSES $117,233 TOTAL REVENUES $60;157 DEFICIT $57:076 1 FY87 Budget estimates prorated for 2 months 2 Minimum (est.) DRACT rl) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE ©P.O.BOX 196300e ANCHORAGE,ALASKA 99519-6300 ®PHONE 907-563-7494TELEX:CHUGACH AHG (090)25 265 TELECOPIER: 907-564-0632 October 27,1986 John Cooley,ChairmanAlaskaIntertieOperating Commitéee@CT 30 A931c/o Municipal Light and Power 1200 East First Avenue Anchorage,AK 99501 Dear John: Please be advised that due to the press of other duties, Mr.John Marshall will be replaced by Mr.Tom Lovas,Chugach's Manager of Planning,as Chugach's designated representative on the Operating Committee effective December 1,1986.Mr.Marshall will continue to participate on various subcommittees and will serve as an alternate along with Mr.Ray Duncan. By way of background,Mr.Lovas has been with Chugach in his present capacity since December of last year.Prior to coming to Chugach,he was Supervising Planning Economist for Montana Power with whom he was employed for six years. Sincerely, (Nb"ufGaryL.il kham Assistant General Manager GLD/TSM/pkd 2/117 cc:L.Colp,FMUS J.Hall,MEA S.Matthews,HEA E..Morris,APA'* B.Orr,GVEA XO.Beck. Record Copy rie wate POO oop ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,JULY 16,1986(AT ALASKA ELECTRIC GENERATION &TRANSMISSION COOPERATIVE) Attendance: Sam Mathews Alaska Electric &Generation Cooperative (AEG&T) Jim Hall Alaska Electric &Generation Cooperative Harry Beck Alaska Power Authority (APA) John S.Cooley Anchorage Municipal Light and Power (ML&P)John C.Marshall Chugach Electric Association (CEA) Bob Orr Golden Valley Electric Association (GVEA) Marvin Riddle Golden Valley Electric Association The meeting was called to order by Chairman John Cooley at 1:53 p.m.in the Executive Conference Room at Homer Electric Association. Minutes of the May 21,1986 meeting were distributed.Chairman John Cooley asked if there were any corrections or amendments that should be made to them.There were none.John Marshall then moved that the minutes be approved.The motion was seconded by Bob Orr and the motion was passed unanimously. The agenda was then modified by inserting under New Business,"F". Relaying." Marvin Riddle distributed a summary of the electric power dispatcherworkshopspreparedbytheUniversityofAlaska-Fairbanks (UAF).He then discussed the contents of the summary.He indicated that approximately 16-20 dispatchers attended the training this year including,for the first time,personnel from Copper Valley Electric Association.Bob Orr stated that he feels the course is getting better every year.Marvin Riddle concluded that the course was well received by the dispatchers. Sam Mathews discussed the activities of the Reliability Subcommittee at their meeting of July 9,1986.Minutes of these minutes were distri- buted.Sam Mathews distributed copies of the Data Base Management Agreement between UAF and the Operating Committee.John Marshall indicated that Chugach Electric's legal counsel had approved the language of the Data Base Management Agreement.Sam Mathews then distributed copies of the Power Flow and Stability Analysis AgreementbetweenUAFandtheOperatingCommittee.He stated that the ReliabilitySubcommitteehadreviewedandrevisedthePowerFlow&Stability Analysis Agreement.He then discussed the major points of this revisedAgreement.Harry Beck indicated that Steve Haagenson had provided lastminuterevisionstothisAgreementbyphone.Harry Beck then requested that the Operating Committee consider these revisions during Work Session. 5801/032 Under APA Status Update,Harry Beck noted that signature (final version)copies of the Maintenance Agreements were being prepared and wouldshortlybesubmittedtoGVEA&AEG&T.He stated that Bob Orr had said that the Maintenance Agreement with GVEA could not be finalized until the issues of (1)spare parts,(2)VHF repeater at Cantwell,(3)partsstoragebuildingatHealyand,(4)special tools were satisfactorily resolved.Bob Orr then explained the nature of these issues. Harry Beck then reported that information had been received from MEA for inclusion in the final Alaska Intertie FY87 Budget.Jim Hall stated that this information consisted of a revised Maintenance budget and financial information relating to the Transmission Service calculations. Harry Beck then said that the budget packages were now being prepared and would soon be distributed to the General Managers.He concluded that FY88 would be the first year that the budget process would be followed in its complete entirety. Discussion then turned to the upcoming testing of the Intertie SVS. Bob Orr said that this test should clearly indicate that phase voltage imbalances exist on the Intertie.He also requested that GVEA's letter to the Power Authority dated April 28,1986 concerning this subject be included in the Intertie minutes.John Marshall stated that CEA would be .monitoring negative sequence currents on their Beluga-Pt Mackenzie circuits during the testing. Harry Beck then summarized the activities and resolutions from the meeting of the Special Subcommittee on Billings/Accounting conducted on June 11,1986.He stated that the group had endorsed the policy of reimbursing "operations on budget -maintenance on actuals."He stated that the Subcommittee had discussed the need for monthly management summaries concerning billings and budget.He further indicated that the Power Authority was presently developing the billing and reporting procedures associated with this subject.The subject of billing scheduled reserves on the Intertie was then discussed by the Subcommittee members.No concensus of opinion was reached on this issue. There were no visitors present at the meeting. There was no Old Business. Under New Business,Marvin Riddle indicated that the Dispatch/Scheduling Subcommittee and the utilities need to receive copies of the revised plan concerning the testing of the SVS.Bob Orr stated that the totalestimatedutilitycostfortestingwas$20,000.He further stated that GVEA was absorbing $15,000 of this total cost.He indicated that thenexttimetestingofthiskindoccurred,GVEA would require that theutilitiessharethecostequally.Harry Beck indicated that the PowerAuthoritywasbearingthelion's share of the total costs for testing:costs of the Power Authority,Morrison-Knudsen,General Electric and Commonwealth Associates. 5801/032 Discussion then proceeded to the subject of reimbursing the Operators for cost of Intertie operation during the period that the Testing Agreement was in force.John Cooley indicated that ML&P had submittedbillingstothePowerAuthorityforreimbursementforthisservice.Bob Orr indicated that GVEA had not.He further indicated that it was his understanding during the negotiations prior to the signing of the Testing Agreement that all parties would absorb their own costs for operation during this period.Harry Beck indicated that the Power Authority was still considering whether these billings were legitimate reimbursable expenses are not. Under Reliability,the UAF Agreements for studies (Data Base ManagementandPowerFlow&Stability Analysis)were then discussed.Harry Beck introduced the additional review comments of Steve Haagenson.The Operating Committee then discussed the changes and revised the Agree- ments accordingly.Harry Beck was then directed to make the approved changes to both Agreements.Bob Orr then stated that the data bases created from the studies will be very useful to all of the Intertie Participants. Discussion then turned to Insurance.John Cooley read the letter from the Power Authority to the Operating Committee dated July 16,1986 concerning insurance.He stated that the Alaska Intertie Agreement(AIA)has to be revised as the utilities cannot obtain the level of insurance coverage required by the Agreement.Bob Orr indicated that a cap has to be established on each Participant's uninsured liability. It was the concensus of the Committee that the AIA has to be changed to incorporate lower limits for coverage and to effectively deal with the subject of self-insurance.Bob Orr stated that the biggest violator of the self-insurance provisions is the Power Authority.He recommendedthatthePowerAuthoritybetaskedwithamendingtheAIAinregardsthe insurance problems facing the Participants. Under Relaying,the recent trip of Intertie breaker 538 at Teeland was discussed.The zone 3 relay at Douglas was identified as having a problem with its wiring circuitry resulting in instantaneous tripping(improper)of the breaker on zone 3 coverage instead of the designed 60 cycle delay.Jim Hall indicated that he had made temporary changes tothewiringtoinhibitthismisoperation.John Marshall stated that thequestionsofwhoistoreviewandchangeintertierelaysettingsneeds to be resolved.John Marshall and Harry Beck stated that the Relaying Subcommittee should be tasked with reviewing all Intertie relaying settings.Bob Orr suggested that the AIA be researched to identifywheretheresponsibilityforrelayingoftheIntertielies. At 4:30 p.m.,under formal Operating Committee action,Bob Orr motionedthattheDataBaseManagementContractbetweentheUniversityofAlaska-Fairbanks and the Operating Committee be approved as amended andthattheChairmanbedirectedtoenterintotheContractwithUAF.The motion was seconded by Sam Mathews and was approved unanimously by those present. 5801/032 Sam Mathews motioned that the technical provisions (i.e.,SpecificationsandProposal)of the Power Flow and Stability Analysis Contract between the University of Alaska-Fairbanks and the Operating Committee and the Contract itself be approved as amended and that the Chairman be directed to enter into the Contract with UAF.The motion was seconded by JohnMarshallandwasapprovedunanimouslybythosepresent. Chairman John Cooley then entertained a motion to direct the Alaska Power Authority to initiate the process to revise the Alaska Intertie Agreement in order to resolve the outstanding problems contained withinitconcerning(1)self-insurance by the Participants,(2)limits ofcoveragerequiredoftheParticipantsand,(3)the lack of limits on each Participant's uninsured liability.Sam Mathews so moved.The motion was seconded by John Marshall and was approved unanimously by those present. Bob Orr motioned to direct the Alaska Power Authority to requires documentation from all Participants concerning their required insurance coverage per the Alaska Intertie Agreement,review and report on the documentation to the Operating Committee.The motion was seconded by Sam Mathews and was approved unanimously by those present. The Chairman then directed the RELIABILITY SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to consider the GeomagneticallyInducedCurrent(GIC)proposals from UAF. The Chairman then directed the RELAYING SUBCOMMITTEE TO MEET at the Subcommittee Chairman's direction to consider the review of the SVS testing. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,SEPTEMBER 17,1986,AT 9:00 A.M.IN THE CONFERENCE ROOM AT GOLDEN VALLEY ELECTRIC ASSOCIATION AT 758 ILLINOIS STREET,FAIRBANKS,ALASKA. John Marshall then motioned for the meeting to adjourn.Harry Beck seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 4:45 p.m. Respectfully submitted, ah L.(Bech for Edwin L.Morris,Secretary Alaska Intertie Operating Committee 5801/032 Attachments: ra September meeting agenda University of Alaska-Fairbanks memorandum to Dispatch/Scheduling Subcommittee dated June 26,1986 Data Base Management Agreement (revised)Between University of Alaska-Fairbanks and Alaska Intertie Operating CommitteePowerFlowandStabilityAnalysisAgreement(revised)Between University of Alaska-Fairbanks and Alaska Intertie Operating Committee Letter from Alaska Power Authority to Intertie Operating Committee dated July 16,1986 Letter from Golden Valley Electric Association to Alaska Power Authority dated April 28,1986 Minutes of Reliability Subcomittee meeting of July 9,1986 5801/032 *UNIVERSITY OF A ASKA Institute of Northern Engineering Engineering Research Center MEMORANDUM TO:Mr.Marvin Riddle Golden Valley Electric Association P.O.Box 1249 Fairbanks,AK 99707 FRM:John Aspnes,Robert Merritt and George MulliganWorkshopCoordinators Electrical Engineering Department DATE:26 June 1986 SUBJECT:Summary of Electric Power Dispatcher Workshops The two Advanced Dispatcher Workshop sessions (2 Jume-6 Jume and 9 June-13 June)were appraised as very successful and beneficial to all in attendance.The dispatchers were first rate as students with excellent attitudes and questions.The appraisal is based on their written opinions which are enclosed,their comments to us at the close of each session,and our own observation of classroom discussion and interest. The enclosed course outline was largely followed.This year there was increased emphasis on SVS principles and long transmission line principles.Both topics were first covered in lecture and then the principles were reinforced by amll-scale laboratory demonstrations. Field trips were taken to the Gold Hill substation and to the Golden Valley Electric Association SCADA center.Marvin Riddle conducted us on a very thorough tour of the substation with particular emphasis on the SVS facility.Henri Dale demonstrated the wide variety of functions which the SCADA system can perform. We also think that a significant benefit is derived fram the dispatchers meeting each other and having the opportunity to discuss system practices and problems.We,therefore,encouraged them to enter into classroom discussion among themselves on any topic we were covering. If more information is desired,please let us know.We thank you for your interest in and support for these dispatcher workshops.We areenthusiasticaboutthestudentinterestshownandenjoyedparticipatinginthisworthwhileprogram. JS:RB:GM:062086 Enclosure a mmm me ems COMMENTS Most of the information given in class was a learning experienceforme.I feel I now do have a much better grasp on the overall inter- tie (Anchorage/Fairbanks)operation taught in class.I enjoyed the GVEA field trip. I thought the course was designed very well as to the level of theory both instructors used especially not knowing our backgrounds. I thought both field trips were of great value.Being able to meet some dispatchers of the other interconnected campanies and talking out their problem areas was helpful. I enjoyed this week and I am sure it will help me in the future. Thanks. I enjoyed all subjects,etc.,covered,a lot of the ideas relating to dispatching between several utilities was of great surprise to me, being limited by working in such a small operation.However,seeing the way it is done was a real eye opener and I enjoyed seeing it.Some of the electrical principles,etc.,cleared up a lot of personal misconception.Enjoyed it. In general a very good course,a little too mich math perhaps.But that is just my opinion. Field trips very good.I need to see what I have been told. All in all very good,I got lost in the heavy theory though. Thanks much. More emphasis on field trips,substation and SCADA control,toexplainordemonstratesystemoperations. Less theory as crystal formation -more information on SVS operationatla's level. Math (equations)portion(s)of lectures may have been past many student's levels.This could be eliminated or controlled to make the time more useful. The field trip to Gold Hill sub was very good. Heavy calc.on most cases not important -too soon forgotten - better to say "take my word for it"and go to more practical solutions. More background on relays and constructions of switches,breakersandtheoryofprotectionmighthelp(relay coordination).Best year yet. I felt the course was very well taught.Preparation was excellent by both instructors and field trips were nice. My personal observation is that possibly the theoreticaldevelopmentsofsomeofthesubjectsshouldbeshortened,as we will probably not remember how to do the derivations,and additional instruction or field time in the actual use of these procedures or concepts. The overall level of my understanding has been raised.I thank youverymuch. One possible suggestion for next year would be to take atransmission/generation problem fram each of the utilities involved. This would provide something of interest on the scale of each company instead of always using textbook problems which are always of a south-48 magnitude. Possibly a few more small experiments. The class itself was interesting and fun.Very worthwhile. The sections I found least helpful,since I have previous power plant experience were: l.prime movers; 2.system load as pertains to systems not configured as ours is;and3.econ dispatch-unit commitment (our system is too small to concern itself heavily with unit commitment). In general,references to the systems configured in the lower 48,except as example to say they exist,really don't have pertinence to our needs on the Alaska inter-tie utilities.I found the sections on:real/reactive power;instrument xformers; relays;SVS;stability;the field trips were excellent.The course was very helpful to me. Best parts:the whole program was good and covered topics which were all interesting.We have in our operation a real wealmess with incremental costs,economic dispatch which should be addressed,and this program may help develop this. My background is not electrical engineering and the explanations were camplex enough to be interesting but not too carplicated tounderstand.The SVS system explanation was very good in both the explanations and model. The SCADA explanation and demonstration definitely showed the possibilities that that system has. Worst parts:seeing Golden Valley's control room -it makes ours seem like a real mom and pop operation by camparison. I felt this was a very good course and you covered most of the material very well.I enjoyed the field trips and maybe would havelikedtospendmoretimewithGVEA.It would be very helpful to cover more of problems that have occurred with inter-tie line. Best parts: l.field trip to GVEA SVS and discussion including demonstration of thyristors in lab; 2.interactions among students -ways practical problems were approached; 3.better this year due to less complicated mth; 4.generally a very good presentation;and 5 the reference material is appreciated. Worst parts: .poor ventilation of building; -some of the carplicated math went a bit over my head; .even more interaction among students would be better;and .a field trip to the university power plant would be very interesting.hmWNFeThe last two days of the course were the more beneficial to me as it was closer to what we really have to be concerned with as operators. It is also necessary to know just how the electrical theory is derived, but as operators,we don't set up operational criteria,as it usually is provided by the engineering department,such as line voltage and amperage limits,etc.However,it was all very interesting.We do need to utilize more specific information about our own systems in Alaska for use as examples in class. Helpful: 1.|MW/MVAR and how to change (+or -);2.power flow (some formulas unhelpful); 3.relay principals; 4.GVEA operation display and substation;and 5.SVS demonstration and lab dem. Unhelpful: 1.binary carp counting;and 2.solid state class on diodes. Would be very helpful if we could actually practice on GVEA's training console -dispatch procedures in emergency situations. Class very helpful to me in my job as power dispatcher.Thank you. The most helpful parts of this seminar,to me,were the sections oneconomicdispatchandthetriptoGVEAcontrol.As an operator at MUS it was very helpful to have a better understanding of how power is to be dispatched to,and received from, other systems.Some of the least important was the load flow solution although I'm not discounting their importance overall. Overall,I think all the subject were covered very well. ELECTRIC POWER DISPATCHER WORKSHOP June 2 -June 6,1986 and June 9 -June 13,1986 at the University of Alaska-Fairbanks ADVANCED COURSE QUTLINE Day1 AM Prime Movers a)Gas turbines b)Combined cyclec)Steam R.P.Merritt Economic Operation George Mulligan a)System loadb)Unit commitment c)Economic dispatch I Day2 AM Rotating Machines a)DC excitation b)Brushless exciters c)Synchronous generatorsd)Real and reactive power generation R.P.Merritt PM Economic Operation George Mulligan a)Economic dispatch -II b)System frequency control - c)Interchange pricing Day3 AM System Protection R.P.Merritt a)Circuit breakers b)Instrument transformers c)Relays 1)magnitude2)directional 3)ratio 4)differential 5)pilot d)Transmission line protection e)Differential protectionf)Underfrequency relays Solid State Devices and SVS R.P.Merritt a)Semiconductors b)Diodes c)SCR's &Triacs d)SVS Principles Day3 PM Stability George Mulligan a)Transmission line equivalent circuitsb)Power flow through a transmission linec)The stability problemd)Steady-state stabilitye)Transient stabilityf)Swing equationg)Equal-area criterionh)Solving the swing equationi)Underfrequency load shedding Day4 AM Load-flow solutions and control a)Data requirements George Mulligan b)Gauss-Seidel and Newton-Raphson methods of solution c)Information contained in load-flow solution d)Control of real and reactive power flow and system voltages 1)Generator controls 2)Capacitor and reactor banks 3)Load tap changing transformers4)Static var systems Day4 PM Field Trip to GVEA Substation Day§ AM Supervisory Control and Data AcquisitionSystems(SCADA)at GVEA a)Power flow b)Transactions c)Transaction evaluationd)Data acquisition|e)SCADA hardware f)Automatic load shed g)Spinning reserve SCADA/Communications Henri Dale R.P.Merritt DATA BASE MANAGEMENT AGREEMENT BETWEEN UNIVERSITY OF ALASKA-FALRBANKS AND ALASKA INTERTIE OPERATING COMMITTEE by and between the University of Alaska-Faifbanks and the Alaska Intertie Operating Committee. This agreement (hereinafter peferred to as Agreement)ismadeandenteredthis___18 day of >1986 IN WITNESS WHEREOF,the signatories to this Agreement, consisting of (1)Signature Page,(2)Specifications For Data Base Management,and (3)University of Alaska- Fairbanks Proposal,"Alaska Intertie And Data Base Management",have caused this Agreement to be executed in duplicate by their duly authorized officers or representatives as of the day and year first above written. UNIVERSITY OF ALASKA-FAILRBANKS Principal Investigator ALASKA INTERTIE OPERATING COMMITTEE Chairman SPECIFICATIONS FOR DATA BASE MANAGEMENT I.WORK INCLUDED A.SCOPE OF WORK 1.The Work comprises the completion of all tasks identified in the Contract.These tasks involve the management and periadic updating of the Master &Utility Data Bases. B.CHANGES IN THE WORK 1.Owner,without invalidating the Contract,may order Changes in the Work consisting of additions, deletions,or modifications,the Contract Sum and Schedules being adjusted accordingly. 2-Changes in the Work shall be authorized by written Change Order signed by the Owner and Engineer. 3.Contract Sum may be changed anty by Change Order. 4.Cost or credit to Owner from a Change in the Work shall be determined by mutual agreement between Engineer and Owner. Il.RESPONSIBILITIES OF PARTIES A.ENGINEER 1.Engineer shall submit to Owner in writing al] requests for information and data relevant to the Work. 2-Engineer will ensure that only Engineer has access to the Master Data Base for editing purposes. 3.Engineer will take all reasonable measures to ensure that the Master Data Base is not changed or modified except as provided for in performing the requirements of the Contract. 4.Engineer will take all measures necessary to ensure that the Master Data Base and the Utility Data Bases are not damaged or lost or otherwise rendered inoperative for the purposes for which they are to be utilized.Safeguarding of the Master Data Base and the Utility Data Bases is an essential element of this Contract. Engineer shall provide Utility with full access (i.e.file read &write permissions)to the Utility Data Base and limited access (i.e.file read permission anly)to the Master Data Base through the University of Alaska Computer Network (UACN). Engineer will perform one power flow and stability case computer analysis at each instance of Master Data Base updating to ensure that the data being submitted is consistent with the data entry requirements of the power flow and stability analysis programs. OWNER 1.Owner shall provide to Engineer ali information and data relevant to the Work in a form and manner as specified by Engineer. Quner shall submit all information and data to Engineer in a timely manner consistent with the Contract Schedules. Owner shall review all progress reports submitted by Engineer and shall notify Engineer in writing of the results of these reviews.These reviews will be provided to Engineer in a timely manner consistent with the Contract Schedules. Owner shall notify Engineer in writing of all requests for updating and upgrading of the Master Data Base.Updating and upgrading of the Master Data Base will be performed at least annually. Quner's request for updating and upgrading of the Master Data Base shall constitute a Notice to Proceed for performing these tasks. UTILITY 1.Utility shall provide to Owner all information and data relevant to the Utility Data Base in a form and manner as specified by Owner. Utility is solely responsible for the adequacy and accuracy of all data and information provided to Owner.Utility shall submit all information and 'data to Owner in a timely manner consistent with the Contract Schedules. Utility will provide Owner with updates to Utility Data Base when so directed by Owner. Iil. Iv. Utility shall review all progress reports submitted by Engineer as they relate to the Utility Data Base.Utility shall notify Owner in writing of the results of these reviews. Utility shall have sole proprietorship of and responsibility for the Utility Data Base.Access to and use of the Utility Data Base is subject to the written approval of Utility.Utility will take all measures necessary to ensure that the Utility Data Base is not damaged or lost or otherwise rendered inoperative for the purposes for which it is to be utilized. SUBMITTALS A.SUBMITTALS 1.Engineer submittals include requests for Utility Data Base information and data,progress reports and data base revisions. Owner submittals include progress report reviews, Utility Data Base information and data,Changes to the Contract Schedules and Changes to the Work. SCHEDULES A.TIME 1.Time of commencement of Contract is the date as 2. specified by the Signatories of this document. Date of Completion of the Work is the date certified by Owner when the Work is fully complete so that Owner can utilize the Work for the use for which it is intended. All time limits stated in the Proposal are of the essence of the Contract.If Engineer is delayed at any time in the progress of the Work by Changes ordered in the Work,conditions not reasonably expectable,causes beyond the Engineer's control, failure of Owner to comply with responsibilities of Owner under this Contract,or by other cause which Owner determines may justify the delay,then Contract Schedules may be modified and Contract Time may be extended.If Engineer determines that a delay of this nature has occurred and that it warrants a change to the Contract Sum,then Engineer shall request in writing that Owner issue a Change Order authorizing Changes in the Work. 4.Contract Schedules may be changed or modified by mutual agreement. V.PAYMENTS A»CONTRACT SUM 1.The Qwner shall pay Engineer for performance of the Work,subject to additions and deductions by Change Order,the Contract Sum of Forty Eight Thousand Six Hundred Fourteen Dollars ($48,614). 2-The Contract Sum is determined as specified in the Proposal. B.PROGRESS PAYMENTS 1.Based upon applications for Payment submitted to the Owner by Engineer,Owner shall make progress payments to the Engineer.Ninety (90%)of the amount due shall be paid by Quner to Engineer within thirty (30)days after submission of the application for Payment. 2.Engineer shall provide Owner with a written progress report concerning the completion of the Work to accompany each application for Payment. 3.Approval of the Application for Payment by Owner shall be issued following approval by Quner of Engineer's progress reports. C.FINAL PAYMENT 1.Final payment,constituting the entire unpaid balance of the Contract Sum (i.e.the remaining 10%of the Contract Sum),shall be paid by Owner to Engineer when the Work has been completed and the Contract fully performed. VI.OTHER A.INDEMNIFICATION 1.To the fullest extent permitted by law,Engineer shall indemnify and hold harmless Owner and Utility and their agents,officers and employees from and against all claims,damages,lasses and expenses sustained by any person or property due to Engineer's acts or omissions under this Contract. B.TERMINATION 1.Either Owner or Engineer has the right to cancel the Contract for any reason including its sole and absolute discretion,in whole or in part,upon the Payment to the Engineer for services rendered up to the time of cancellation.Upon such notice of cancellation,Engineer shall stop the performance of the Work hereunder except as may be necessary to carry out such notice of cancellation,and take any other action toward termination of the Work which Quner may reasonably direct. VII.DEFINITIONS A.DEFINITIONS Contract -The documents constituting the entire agreement between Ouner and Engineer, except for modifications,which are the Signature Page,this Specification and the Proposal to which it applies. Engineer -The Institute of Northern Engineering of the University of Alaska-Fairbanks. Master Data -The composite Utility Data Bases Base describing the interconnected ;Anchorage-Fairbanks electrical network.The initial Master Data Base "is the interconnected system data base developed for the University of Alaska-Fairbanks final report (revised),"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. Owner -The Intertie Operating Committee.The function and authority of Owner in its relationship to Utility is defined in the Alaska Intertie Agreement. Proposal -The proposal from the University of Alaska-Fairbanks to the Intertie Operating Committee,"System Data Base Management"dated March 1986. Utility --Any ane of the participating utilities to the Intertie Operating Agreement that maintain a Utility Data Base as a subset of the Master Data Base at UACN. Utility Data Base The detailed information and data describing the utility system in a computer structured format residing in the Master Data Base at UACN.The initial Utility Data Base is the individual utility data base developed for the University of Alaska-Fairbanks final report (revised),"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. SE.86.48 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE ALASKA INTERTIE DATA BASE MANAGEMENT by Institute of Northern EngineeringUniversityofAlaska-Fairbanks Fairbanks,Alaska 99775-1760 March 1986 ;Acad MellnD.Aspnes fe T.0.Robérts,DirectorPrincipalInvestigatorInstituteofNorthern Engineering eor Tgan \oints ChancellgrCo-Investigator WO iniversie Alaska-Fairbanks INTRODUCTION Thts proposal requests continuing support for management and update of a data base developed under a previous proposal titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System." The dynamic stability study proposal was funded by Anchorage Municipal Light and Power (AMLP),Chugach Electric Association,Inc.(CEA), Fairbanks Municipal Utilities System (FMUS)and Golden Valley Electric Association,Inc.(GVEA).The stability study data base,structured to support the Electric Power Research Institute (EPRI)745 transient- midterm stability program,resides with the 745 code in the University of Alaska computer network (UACN).The four utilities named above and the Alaska Power Authority (APA)have access to this data base and stability program.The Alaska Intertie Operating Committee has indicated an interest in having the data base updated and having electric power system stability studies performed using the revised data base.: PROJECT JUSTIFICATION This proposed project takes advantage of tasks completed under the previous proposal titled "Dynamic Stability Study of the Anchorage- Fairbanks Interconnected Power System."These tasks included assembling a data base for the interconnected Anchorage-Fairbanks electric power systems to be used with the Electric Power Research Institute (EPRI)745 Transient-midterm Stability Program.Five case studies were performed, using the EPRI 745 code.Results are given in the project final report. The resulting data base modeling the Alaska intertie,and the electric power systems it interconnects,resides on the UACN computer network along with a working copy of the EPRI 745 code.The four participating utilities and the APA have access to this data base and EPRI software. Managing and upgrading the data base will help participating utilities obtain the most from their investment in the previous project. In addition,this project,like the previous one,is an investment in educating future power engineers for the Alaskan utility industry. PROJECT SCOPE Project tasks to be performed include: 1.Manage and update the data base currently residing on the UACN computer.This includes making changes to the master copy of the data base at least annually,using data supplied by each utility. Also,one power flow and stability analysis case will be run with the revised data to ensure that the modified data base is an acceptable input to the computer programs. As in the recently completed project,each participating utility will have access to the master data base from its own account but will not be able to directly modify it.Individual user account charges from UACN are the responsibility of each utility PROJECT SCHEDULE Timetable °Tasks June 1986 -October 1987 Update and review system data base; verify new data base works with computer programs.These tasks will be performed at least twice during the contract period,with one revision to be completed by October 13,1986 and a second revision to be completed by October 31,1987.This schedule assumes revised data base information will be received from all participating utilities by July 15, 1986 and,for the second revision, July 15,1987. BUDGET 1 July 1986 -30 September 1987 FY87 FY88 SALARIES 1.Principal Investigator,J.Aspnes4wks@$36.06/hr $2,885 $2,8852.Principal Investigator,G.Mulligan4wks@$28.84/hr 2,308 2,3083.Graduate Research Students 1200 hrs @ $10.00/hr 6,000 6,000 LEAVE BENEFITS 1.16.1%of A.1 and A.2 836 836 STAFF BENEFITS 1.24.6%of A.1,A.2 and B.1 1,483 1,483 TRAVEL 1.Travel between Anchorage and Fairbanks (20 trips @ $250)2,500 2,500 SERVICES 1.Documentation and reports 400 400 2.Telephone 250 250 3.Computer support -:350 350 SUPPLIES 1.Photocopy and expendables 350 350 2.Magnetic tape 100 100 OVERHEAD 1.39.2%of MTDC (items A through F)6,845 6,845 FY TOTAL $24,307 $24,307 PROJECT TOTAL $48,614 POWER FLOW AND STABILITY ANALYSIS AGREEMENT BETWEEN UNIVERSITY OF ALASKA-FAIRBANKS AND ALASKA INTERTIE OPERATING COMMITTEE This agreement Chereinafter referred to as Agreement)is made and entered this _________day of ______»1986 by and between the University of Alaska-Fairbanks and the Alaska Intertie Operating Committee. IN WITNESS WHEREOF,the signatories to this Agreement, consisting of (1)Signature Page,(2)Specifications For Data Base Management,and (3)University of Alaska- Fairbanks Proposal,"Alaska Intertie Power Flaw And Stability Analysis",have caused this Agreement to be executed in duplicate by their duly authorized officers or representatives as of the day and year first abave written. UNIVERSITY OF ALASKA-FALIRBANKS Principal Investigator ALASKA INTERTIE OPERATING COMMITTEE Chairman SPECIFICATIONS FOR POWER FLOW AND STABILITY ANALYSIS I.WORK INCLUDED A.SCOPE OF WORK 1.The Work comprises the completion of all tasks identified in the Contract.These tasks involve the performing of power flow and stability case studies of the interconnected Anchorage-Fairbanks electrical system. The work is subject to the completion of tasks outlined in a similar Contract,"Data Base Management Agreement Between University of Alaska- Fairbanks And Alaska Intertie Operating Committee."These tasks involve the management of the Master and Utility Data Bases which are the foundation for the performance of the power flow and stability case studies. B.CHANGES IN THE WORK 1.Quner,without invalidating the Contract,may order Changes in the Work consisting of additions, deletions,or modifications,the Contract Sum and Schedules being adjusted accordingly. Changes in the Work shall be authorized by written Change Order signed by the OQuner and Engineer. Contract Sum may be changed only by Change Order. Cost or credit to Owner from a Change in the Work shall be determined by mutual agreement between Engineer and Owner. II.RESPONSIBILITIES OF PARTIES A.ENGINEER 1.Engineer shall submit to Owner in writing all requests for information and data relevant to the Work. Engineer will take all reasonable measures to ensure that the EPRI software is not changed or modified except as provided for in performing the requirements of the Contract. Engineer will take all measures necessary toa ensure that the EPRI software is not damaged or lost or otherwise rendered inoperative for the Purpose for which it is to be utilized. Safeguarding of the software is an essential element of this Contract. Engineer shall provide Owner with limited access (i.e.file execute permission only)to the EPRI software through the University of Alaska Computer Network (UACN). OWNER 1.Owner shall provide to Engineer all information and data relevant to the Work in a form and manner as specified by Engineer. Quner shall submit all information and data to Engineer in a timely manner consistent with the Contract Schedules. Owner shall review all progress reports submitted by Engineer and shall notify Engineer in writing of the results of these reviews.These reviews will be provided to Engineer in a timely manner consistent with the Contract Schedules. Owner shall approve and submit to Engineer al] power flow and stability case studies to be performed by Engineer. UTILITY 1.Utility shall provide to Owner all)information and data relevant to the Work in a form and manner as specified by Owner. Utility shall submit all information and data to Owner in a timely manner consistent with the Contract Schedules. Utility is solely responsible for the adequacy and accuracy of all data and information provided to Quner. Utility shall review all progress reports submitted to Ouner by Engineer.Utility shall notify Owner in writing of the results of these revieus. Ill. IV. V. SUBMNITTALS A.SUBMITTALS 1.Engineer submittals include requests for information and data,progress reports,an interim report and a final report. Owner submittals include progress report reviews, information and data,case study approvals, Changes to the Contract Schedules and Changes to the Work. SCHEDULES A. PAYMENTS A. TIME 1. 2. Time of commencement of Contract is the date as specified by the Signatories of this document. Date of Completion of the Work is the date certified by Owner when the Work is fully complete so that Owner can utilize the Work for the use for which it is intended. All time limits stated in the Proposal are of the essence of the Contract.If Engineer is delayed at any time in the progress of the Work by Changes ordered in the Work,conditions not reasonably expectable,causes beyond the Engineer's control, failure of Owner to comply with responsibilities of Owner under this Contract,or by other cause which OQuner determines may justify the delay,then Contract Schedules may be modified and Contract Time may be extended.If Engineer determines that a delay of this nature has occurred and that it warrants a change to the Contract Sum,then Engineer shall request in writing that Owner issue a Change Order authorizing Changes in the Work. Contract Schedules may be changed or modified by mutual agreement. CONTRACT SUM 1.The Owner shall pay Engineer for performance of the Work,subject to additions and deductions by Change Order,the Contract Sum of Fifty Two Thousand Seven Hundred Three Dollars ($52,703). VI. 2.The Contract Sum is determined as specified in theProposal. B.PROGRESS PAYMENTS 1.Based upon applications for Payment submitted ta the Owner by Engineer,Owner shall make progress Payments to the Engineer-Ninety (90%)of the amount due shall be paid by Owner to Engineer within thirty (30)days after submission of the application for Payment. Engineer shall provide Owner with a written progress report concerning the completion of the Work to accompany each application for Payment. Approval of the Application for Payment by Owner shall be issued following approval by Owner of Engineer's progress reports. C.FINAL PAYMENT 1. OTHER Final payment,constituting the entire unpaid balance of the Contract Sum (i.e.the remaining 10%of the Contract Sum),shall be paid by Owner to Engineer when the Work has been completed and the Contract fully performed. A.INDEMNIFICATION 1.To the fullest extent permitted by law,Engineer shall indemnify and hold harmless OQuner and Utility and their agents,officers and emplayees from and against all claims,damages,losses and expenses sustained by any person or property due to Engineer's acts or omissions under this Contract. B.TERMINATION 1.Either Owner or Engineer has the right to cancel the Contract for any reason including its sole and absolute discretion,in whole or in part,upon the Payment to the Engineer for services rendered up to the time of cancellation.Upon such notice of cancellation,Engineer shall stop the performance of the Work hereunder except as may be necessary to carry out such notice of cancellation,and take any other action toward termination of the Work which Owner may reasonably direct. VII.OEFINITIONS A.DEFINITIONS Contract -The documents constituting the entire agreement between Quner and Engineer, except for modifications,which are the Signature Page,this Specification and the Proposal to which it applies. Engineer -The Institute of Northern Engineering of the University of Alaska-Fairbanks. EPRI saftware -The Electric Power Research Institute (EPRI)745 Transient- Midterm Stability Program.The computer saftware used to perform the power flow and stability case analyses. Master Data -The composite Utility Data Bases Base describing the interconnected Anchorage-Fairbanks electrical network.The initial Master Data Base is the interconnected system data base developed for the University of Alaska-Fairbanks final report (revised),"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. Owner --The Intertie Operating Committee.The function and authority of Owner in its relationship to Utility is defined in the Alaska Intertie Agreement. Propasal -The proposal from the University of Alaska-Fairbanks to the Intertie Operating Committee,"Alaska Intertie Power Flow And Stability Analysis"dated July 1986. Utility -Any one of the participating utilities to the Intertie Operating Agreement that maintains a Utility Data Base as a subset of the Master Data Base at UACN. Utility Data Base The detailed information and data describing the utility system ina computer structured format residing in the Master Data Base at UACN.The initial Utility Data Base is the individual utility data base developed for the University of Alaska-Fairbanks final report (revised),"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. INE87.01 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE ALASKA INTERTIE POWER FLOW AND STABILITY ANALYSIS by Institute of Northern Engineering University of Alaska-Fairbanks Fairbanks,Alaska 99775-1760 July 1986 John D.Aspnes i41.D.Robexts,DirectorPrincipalInvestigatorInstituteofNorthernEngineering University of Alaska-Fairbanks University of Alaska-Fairbanks Georgé Mulligan J Vice Chancellor Co-Investigator University of Alaska-Fairbanks University of Alaska-Fairbanks INIRCDUCTION This proposal requests support for continued utilization of a data base developed under a previous proposal titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System."The dynamic stability study proposal was funded by Anchorage Mmicipal Light and Power (AMLP),Chugach Electric Association,Inc.(CEA),Fairbanks Municipal Utilities System (FMUS)and Golden Valley Electric Association,Inc.(GVEA).The stability study data base,structured to support the Electric Power Research Institute (EPRI)745 transient- midterm stability program,resides with the 745 code in the University of Alaska computer network (UACN).The four utilities named above and the Alaska Power Authority (APA)presently have access to this data base and stability program.The Alaska Intertie Operating Conmittee has indicated an interest in having the data base updated and having electric power system studies performed using a revised data base. We propose to perform power flow studies to investigate the operating characteristics of the electric power systems interconnected by the Alaska intertie.In addition,we propose to perform five stability case studies for the same interconnected system. PROJECT JUSTIFICATION This proposed project takes advantage of tasks completed under the previous proposal titled "Dynamic Stability Study of the Anchorage- Fairbanks Interconnected Power System."These tasks included assembling a data base for the interconnected Anchorage-Fairbanks electric power systems to be used with the Electric Power Research Institute (EPRI)745 Transient-midterm Stability Program.Five case studies were performed, using the EPRI 745 code.Results are given in the project final report. The resulting data base modeling the Alaska intertie,and the electric power systems it interconnects,resides on a 785 VAX computer in the UACN carputer network along with a working copy of the EPRI 745 code. The four participating utilities and the APA have access to this data base and EFRI software. Managing and upgrading the existing data base is being addressed in a carpanion proposal.That work,in addition to the analysis tasks suggested in this proposal,will help participating utilities maximize the return on their investment in the previous project.The proposed tasks should help resolve costly operating problems. In addition,this project,like the previous one,is an investment in educating future power engineers for the Alaskan utility industry. PROJECT SCOPE Project tasks to be performed include: 1.perform ten power flow studies to investigate operating characteristics of the electric power systems interconnected by the Alaska intertie. 2.Perform five stability case studies with an updated data base. System analyses performed for this project will use the updated data base.Power flow and stability cases will be determined by the Alaska Intertie Operating Conmittee (IOC)or the Reliability Subcommittee based upon.recommendations by Institute of Northern Engineering (INE)persormel (John Aspnes and George Mulligan).The ICC will be provided with graphic output,program input file listing and a narrative describing each stability case.Power flow program output and a descriptive narrative will be made available for each power flow case. After campletion of the five stability case studies,an interim report containing the above information will be provided to the IOC anda presentation will be made at an ICC meeting. Following a 30 day review and comment period,the IOC my request additional power flow cases to be performed at a cost not to exceed $2,000 per case and additional stability cases to be performed at a cost not to exceed $4,000 per case.This includes case documentation, analysis and report,and excludes travel and presentation costs.These prices will be in effect through February 1988. -2- Turnaround time for an additional power flow case study is anticipated to be 30 days and to be 60 days for an'additional stability case study. Each utility will need to provide data required for the above analyses.Data requirements will be defined by INE and submitted to the ICC, PROJECT SCHEDULE Timetable Tasks July 1986 -December 1986 Update and review system data base per data base management proposal. October 1986-July 1987 Perform five stability case studies and ten power flow studies with the updated data base;prepare and present interim report. Septerber 1987-February 1988 Perform additional power flow and stability case studies as requested by Intertie Operating Conmittee. January 1988-February 1988 Prepare and present final report. BUDGET 1 July 1986 -29 February 1988 SALARIES l.Principal Investigator,J.Aspnes3wks@$36.06/hr 2.Principal Investigator,G.Mulligan 6 wks @ $28.84/hr 3.Secretary 1 wk @ $12.49/hr 4.Graduate Research Students 1,200 hrs @ $10.00/hr LEAVE BENEFITS 1,16.1%of A.1 and A.2 2.18.3%of A.3. STAFF BENEFITS 1.24.6%of A.l,A.2 and B.1 2.26.9%of A.3 and B.2 TRAVEL 1.Mme conference trip and travel between Anchorage and Fairbanks SERVICES 1.Documentation and reports 2.Telephone 3.Computer support SUPPLIES 1.Photocopy and expendables 2.Magnetic tape EQUIPMENT 1,Computer programs OVERHEAD 1.39.2%of MIDC (items A through F) | FYTOTAL PROJECT TOLAL "FY87 FY88 $1,442 $2,885 2,308 4,616 250 250 6,000 6,000 604 1,208 46 46 1,071 2,142 80 80 1,200 1,300 1,000 1,000 500 500 350 350 500 500 100 100 1,995 6,057 8,223 $23,503 $29,200 $52,703 Bill Sheffieia,Scverrcr NNN) Alaska Power Authority State of Alaska July 16,1986 Mr.John S.Cooley,Chairman Alaska Intertie Operating Committee c/o Anchorage Municipal Light &Power 1200 East First Avenue Anchorage,Alaska 99501 Re:Alaska Intertie Insurance Dear John: Three insurance items were unresolved for the FY87 Intertie budget at the last Operating Committee meeting.Those items were: 1)Cost of FY 87 Intertie insurance coverage,and 2)availability and cost of property insurance for the Intertie transmission line facilities,and 3)acceptability of ML&P self-insurance program in complying with the provisions of the contract. Item (1)FY87 Insurance Coverage The boiler machinery and property coverage was placed with anannualpremiumcostof$68,843.The deductible limits are $100,000 for major substation power transformer,$50,000 for majorsubstation(e.g.items and circuit breaker)$25,000 for all other items. Item (2)Transmission Line Coverage Property insurance for the transmission line is not available as underwriters refuse to quote coverages according to Don Hitchcock, Director,Division of Risk Management.However,Mr.Hitchcock was told by the broker that insurance firms in London might quote rates although they are expected to be outrageously high.The broker will seek a quote on the insurance and the deductible level and report back to Mr.Hitchcock. Item (3)ML&P Self-insurance Program The provisions of the ML&P self-insurance program do not meet the contractual requirements as stated in the Alaska Intertie Agree- ment.Information was received today from the Department of 5135/458 PO Box 190869 704 East Tudor Road Anchorage,Alaska 99519-0869 (907)561-7877 Mr.John S.Coo._y July 16,1986 Page 2 Property and Facility Management,Risk Management Division of theMunicipalityofAnchoragethattheselfinsuranceprogrammeetsthe program requirements.However,a reading of Section 17.1 of the Alaska Intertie Agreement states that the self insurance is limited to $250,000 even with Operating Committee and Authority approval. This leaves the options of ML&P obtaining the required coverage from insurance carriers or requesting the amending of the contractual requirements.The contract amendment process may still not result in the parties accepting the ML&P self-insurance program as it is constituted,for meeting the requirements. With the volatile insurance market and the desire of the contract- ing parties to ensure that adequate coverage is provided,I request that ML&P Risk Management Division review your program and the contract for suggesting the best method for ML&P to proceed. Sincerely, fay oe:Btthy Edwin L.Morris Director,Operations and Engineering ELM/cdc cc:Operating Committee Robert D.Heath Gloria Manni Don Hitchcock Harry Beck 5135/458 P.O.BOX 196650 ANCHORAGE,ALASKA 99519-6650Municipality of (907)264-4201 Anchorage Tony xwowues. DEPARTMENT OF PROPERTY AND FACILITY MANAGEMENT Risk Management Division Cer,ee)ovJuly8,1986 ALASK Re ,6 JU 14 PI2:06EdMorris. Alaska Power Authority P.O.Box 190869 Anchorage,Ak 99519 Re:Alaska Intertie Insurance Requirements The Municipality of Anchorage.is covered for liability exposures by the financial resources of the Municipality.Losses including those for which we are contractually liable,are administered under our self-insured claims progran. This is to advise you that the liability insurance requirements of the subject agreement between the Municipality of Anchorage and Alaska Power Authority fall within and are covered by the Self-insured program.mo, We further advise you that the Municipality's Workers Compensation insurance requirements are satisfied through an insured/self-insured program with $350,000 being'the self-insured retention.A certificate of insurance showing proof of the excess workers compensation coverage and a financial statement are enclosed. Unless cancelled earlier,this letter will remain in effect until the expiration or earlier termination of the subject agreement.If this'program is cancelled or materially changed,we will provide you with thirty days'prior written notice. Sincerely, Foren Karen Reddy Insurance AdminiStrator KJR/jrh enclosures 2 te /Cat Acah of-[ASerance wp-Com prehonsiee Prraue! ROON &BLACK, «w<-0 B STREET ANCHORAGE,AK 99503 INC. Fog Meme 8 fo Sy 5 heee iNSUREO OVERAGES sere oyTHISISTOCERTIFYTHATPOLICIES OF INSURANCE LISTED BELOW HAVE BEEN ISSUED TO THE INSURED NAMED ABovE FOR THE POLICY PERIOD INNICATED.HOTWITHSTANOIPG ALY REQUINEMENT,TENT Of COMOIION OF ANY COPIMMACT Of OTHER DOCUMENT WITH RESPECT TO WHICH THIS CENTIFICATE MAY aoeBEISSUEDORMAYFERTAIY,THE INSURANCE AFFORDED BY THE POLICIES DESCRIPED HEREIN IS SUBJECT To ALL THE TERPS,EXCLUSIONS,ANO CONDI-'Ss ¥ MUNICIPALITY OF ANCHORAGE POUCH 6-650 ANCHORAGE,AK 99502 TIONS OF SUCH POLICIES. EN OA a oY aye Rat PL Es x ett SUE LATE (SAVOOr =)vee -6-86pas ihrySutAaean.7 coh ad EsTHISCERTIFICATEISISSUEDASAMATTEROFINFORMATIONONLYANDCONFERS=BetsNORIGHTSUPONTHECEATIFICATEHOLDER.THIS CERTIFICATE DOES NOT AMEND,=»E38"EXTEND CA ALTER THE COVERAGE AFFORDED BY THE POLICIES BELOW.YeljoepeCOMPANIESAFFORDINGCOVERAGEBAix COMPANY A SAFETY MUTUAL CAS CO weySiaCOMPANYerterrenwad COMPANY TheeterreR©toleern COMPANY 1p aLETTERoe4ogeeCOMPANYvetetren= &°eredpaShvaoeANESSiFymga8RDteSLoeBMshot«oan pas O POLICY EFFECTIVE POLICY EXPIRATION LIABILITY LIMITS IN THOUSANDS -Bt:9 TYPE OF INSURANCE POLICY NUMBER Dale \Rateyy,Ch kawceren TREEccT aconecare em GENERAL LIABILITY noon ee|Zé. COMPREHENSIVE FORM INUAY 1 $$Eee, PREMISES/OPERA TIONS PROPERTY aioe[1 UNDERGROUND DAMAGE 1 $fing|__|EXPLOSION §COLLAPSE HAZARD % PROUUCTS:COMPLETED OPERATIONS :--614 PO[|contractuan compinen |&$ "EPENDENT CONTAACTORS DAD FORM PROPERTY DAMAGE PERSONAL INJURY PERSONAL INJURY |$- AUTOMOBILE LIABILITY soony +(UURY ANY AUTO ren perso |S[--}ALL OWNED AUTOS (PRIV PASS)aoa ---+PUURYOTHERTHAN|__|ALL OWNED AUTOS (Pr pace'PER aconeNN|$ HIRED AUTOS PROPERTY NON-OWNED AUTOS OaMacE ($ T)GARAGE LIABILITY waPD|COMBINED |$: EXCESS LIABILITY " od UMBRELLA Fa 2eo |S $Ge OTHER THAN UMBRELLA FORM Sate STATUTORY if aesWORKENS'COMPENSATION SP-1453-AK 1-1-86 1-1-87 $100 JRAGH ACCENT e-_i _AND $500 ,IOISEASE-POLICY LiMn)=FagEMPLOYERS'LABILITY $100 ,{DISEASE EACH EMPLOYEE)ron OTHER ef ESCRIPTION OF OPERATIONS/LOCATIONS/VEHICLES/SPECIAL ITEMS A a ATE HOLDER.«4 -we Te 2 ge ee ye A ef 5 gate, ATTEN:ED MORRIS . PORN 28 (AR Al <2 n-ne j KA POWER AUTHORITY PO BOX 190869 ANCHORAGE,AK 99519 Fa STULL eseeeanenPO reNRONS Sa OTTREOeTRENT Mas =86SHOULD ANY OF THE ABOVE DESCNIBED POLICIES BE CANCELLED BEFORE THE EX-Mae 6PINATION DATE THEREOF,THE ISSUING COMPANY WILL ENDEAVOA TO s MAR 30 DAYS WRITTEN NOTICE TO THE CERTIFICATE HOLDER NAMED TO THE :LEFT,BUT FAILURE TO MAR.SUCH NOTICE SHALL IMPOSE NO OBLIGATION OR LIABALITY OF ANY KINO UPON_THE COMPANY,ITS AGENTS OR REPRESENTATIVES. COMPREHENSIVE ANNUAL FINANCIAL REPORT OF THE | MUNICIPALITY OF ANCHORAGE,ALASKA FOR THE FISCAL YEAR JANUARY 1,1985 TO DECEMBER 31,1985 TONY KNOWLES Mayor Prepared By , DEPARTMENT OF FINANCE BARBARA STECKEL Chief Fiscal Officer BARBARA R.WILLOWS Controller GOLDEN VALLEY ELECTRIC ASSOCIATION INC.Box 1249,Fairbanks,Alaska 99707 Phone 907-452-1151 RECEALASHAS IVEC 8.ot ty April 28,1986 86 MAY 14 PY :39 Ed Morris Assoc.Executive Director Planning &Operations Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 Subject:Alaska Intertie Phase Voltage Imbalance Problems Since the energization of the Alaskan Intertie both the Northern area and Southern area have been occasionally experiencing transmission system phase voltage unbalance problems. We have recently isolated the major portion of the problem to the Alaskan Intertie line itself during lightly loaded conditions (less than 25 MW power flow).We suspect the problem is due to lack of transpositions in the Alaskan Intertie line. With the Northern and Southern areas intertied and 25 MW power flow to the North,MEA is experiencing an approximately 3%phase voltage unbalance on the 138 KV bus at Douglas Substation.At the same time the unbalance is occurring in Douglas it is okay at Healy 138 KV bus,it is within 1/28. With the Northern and Southern areas separated at Teeland and GVEA feeding Douglas load of 3 MW,GVEA is experiencing an excessive unbalance problem on the Healy 138 KV bus.The Healy unbalance is approximately 4%which is adversely affecting the distribution substation circuits at Healy and Nenana.At the same time the Healy unbalance is occurring,the unbalance at Douglas is 2.7%. Any transmission unbalance over 1%is cause for alarm and when it reaches 2%-3%we consider it to be excessive. With the Intertie "open™at Healy and Douglas (total tie line isolated),neither the Northern or Southern systems are experiencing unbalance problems at Healy or Douglas 138 KV buses. GOLOEN VALLEY ELECTRIC At ICIATION INC. John Cooley Page 2 The concern over the Alaskan Intertie not having any transpositions was expressed by the utilities and the Operating Committee at the onset of the project.We were told the lack of transpositions would not create any problems.Would you please look into this matter and advise us of your findings. RobertArb J Manager of System Operations cc:Kelly -GVEA Riddle -GVEA Huber -GVEA Hall -MEA Duncan -CEA Cooley -AML&P Eberle -APA Warnock -MK Operating Committee ¥O Beck #istass eH. Kha, RELIABILITY SUBCOMMITTEE MEETING ANCHORAGE INTERTIE JULY 9,1986 9 A.M.--CEA ENGINEERING CONFERENCE ROOM PRESENT: John Marshall -CEA Harry Beck -APA Larry Hembree =-ML&P Steve Haagenson -GVEA John Aspnes UAF S.C.Matthews -AEG&T PURPOSE: Review Study proposed by Aspnes.Review had been broken down into four categories as requested earlier: 1.DATA BASE MANAGEMENT -Since the criteria for this had been approved by the full Operating Committee, no further actions or comments were necessary. 2.STABILITY AND LOAD FLOW -This was reviewed in some detail.Larry Hembree suggested need for language changes in the scope of work.There were references to load flows relating to overall interconnected system efficiencies.It was felt that this might be interpreted as duplicating work of some of the G&T studies being considered in the political arena.The language changes were made but it was felt that the detail we are getting will not duplicate the other studies which are financial in nature. 3.DATA COLLECTION FOR GEOMAGNETIC DISTURBANCE INVESTIGATION -There has to be a modification of data channels for neutral current monitoring due to changes of Teeland Substation. 4.ANALYSIS OF GEOMAGNETIC DISTURBANCE DATA =-There will have to be some revisions in the schedule. Budgets for the above were also reviewed and Aspnes is to come back with further information regarding costs for extra load flow and stability cases and communication channel costs required for data gathering. The meeting was adjourned at noon. 4.6.Wawfirs S.C.Matthews RELMIN.SCM:ko ec:All in attendance w «7 ITI. IV. V. VI. VIT. VIII. IX.AMIDWOVDD°.eeeeeALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,SEPTEMBER 17,1986 BEGIN at 9:00 A.M. Adoption of prior meeting minutes Approval/modification of agenda Committee correspondence and reports A. Dispatch/Scheduling Subcommittee B.Reliability Subcommittee C. Intertie Status Update (A.P.A.) D.Relaying Subcommittee Visitor comments related to items on agenda Old Business New Business Recess and work session Dispatcher/Scheduling Reliability Relaying Insurance Others Formal Operating Committee action/recommendation Subcommittee assignments Adjournment Meeting location:Golden Valley Electric Association 758 Illinois Street Fairbanks,Alaska 99701 (907)452-1151 3928/591(1) Record Copy File#fet Pho 2-4 ALASKA INTERTIE OPERATING COMMITTEE MEETING WEDNESDAY,MAY 21,1986 (AT ALASKA POWER AUTHORITY) Attendance: Sam Mathews Alaska Electric &Generation Cooperative Jim Hall Alaska Electric &Generation Cooperative Harry Beck Alaska Power Authority Afzal Khan Alaska Power Authority Ed Morris Alaska Power Authority John Stafford Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power John C.Marshal]Chugach Electric Association John Spence Chugach Electric Association Larry Colp Fairbanks Municipal Utilities System Marvin Riddle Golden Valley Electric Association The meeting was called to order by Chairman John Cooley at 9:05 a.m. in the Executive Conference Room at the Alaska Power Authority (APA). Corrected minutes of the March 19,1986 meeting without attachmentsweredistributed.Chairman John Cooley asked if there were any further corrections or amendments that should be made to them.There were none.John Marshall then moved that the minutes be approved as corrected.The motion was seconded by Marvin Riddle and the motion was passed. Minutes of the April 23rd meeting were then reviewed.John Cooley stated that the minutes should be revised on page 7,paragraph 2 to indicate that John Cooley was the Operating Committee Chairman. Marvin Riddle stated that the minutes should be corrected on page 5, paragraph 4,by replacing the third sentence with the "The Operating Committee agreed by consensus to correct the amount shown in the Operating Committee budget for studies by changing the figure $98,900tothatof$100,000 and to reinsert in the budget the amount of$12,000 for secretarial services."Marvin Riddle also suggested that on page 7,paragraph 5,the word "would”should be replaced with"could."He also indicated that on page 6,the last sentence of paragraph 2 should be deleted.Finally,Marvin Riddle moved that the minutes now be approved as corrected.John Marshall seconded the motion.The motion was approved unanimously. The agenda was then modified by inserting under Old Business,"A. Level of Detail for Minutes"and under New Business,"G.Approval of FY87 MITCR Calculation"and "H.FY88 Operating Committee Budget." Marvin Riddle made a presentation on the special meeting of the Dispatch/Scheduling Subcommittee conducted on May 8,1986 at 8:00 4620/558(1) Alaska Intertie erating Committee Meet.uug May 21,1986 Page 2 a.m.in the Conference Room at AML&P.Minutes of the meeting were furnished and attached.Marvin Riddle reported that the meeting was held at the request of APA and concerned the proposed testing of the Static Var Systems (SVS).He then provided a copy of the preliminary test plan to the Operating Committee the discussion of which was the subject of the Subcommittee meeting.Marvin Riddle then discussed the sections of the test plan. After discussing the purpose of each section of the plan,MarvinRiddlethenprovidedtheOperatingCommitteewith(1)a copy of theGVEAlettertoAPA(attached)addressing their concerns and comments subject this test and,(2)a summary of the discussion at the Subcommittee meeting for each test plan section.These summaries included the review comments provided by the Subcommittee members which are noted in the attached copy of the test plan.In addition, the Subcommittee added a final section to the test plan titled, "Financial Consideration."Marvin Riddle indicated that the purpose for this section was to have the Engineer (i.e.Commonwealth Associates)determine the manhour estimates for all of the participants in the test. Finally,Harry Beck indicated that the APA was considering conducting these performance tests on the SVS as this had been a desire on thepartoftheutilitiesallalong.John Stafford added that conducting the performance tests in lieu of the loss test might be more advantageous in terms of cost-to-benefits.He also expressed the concern that the results of any of these tests may point up weaknesses or problems that might have to be addressed or corrected. Sam Mathews discussed the activities of the Reliability Subcommittee at their meeting of April 30,1986 and their work session of May 7, 1986.Minutes of these meetings were not available.Sam Mathews distributed copies of the Data Base Management Agreement between theUniversityofAlaska-Fairbanks (UAF)and the Operating Committee.See attached.This Agreement includes (1)Signature Page,(2)Specifications For Data Base Management and,(3)UAF Proposal, "Alaska Intertie And Data Base Management."Sam Mathews'then discussed the major points of the Agreement.Finally,he requested that the Operating Committee formally adopt the Agreement. John Spence suggested that a written legal opinion on the Agreement relating to liability of the Participants may be in order.Ed Morris stated that the State does not have an attorney available for legal review on behalf of the Operating Committee.John Marshall opined that the Alaska Intertie Agreement might be the umbrella for liability protection of the Operating Committee members involving Operating Committee contracts with other parties.Sam Mathews recommended that the Operating Committee approve the technicalprovisionsoftheAgreement(i.e.Specifications and Proposal).John 4620/558(2) ae Alaska Intertie erating Committee Meer.nag May 21,1986 Page 3 Marshall indicated that the Operating Committee could approve the Agreement subject to legal review. Sam Mathews motioned that the technical provisions of the Agreement(i.e.Specifications and Proposal)be approved and adopted by the Operating Committee.Ed Morris seconded the motion and it was passed unanimously.John Marshall then indicated that he would submit the Agreement for legal review at Chugach Electric Association. Under APA Status Update,John Cooley indicated that the Power Authority had sent the Operating Committee a copy of the proposed summer construction schedule.He stated that the copy that the Committee had received was missing the scope of work attachment. Harry Beck stated that he thought that the construction activities were confined to the Healy and Goldhill substations only.He further stated that copies of the scope of work for the construction schedule would be sent to all Operating Committee members. Harry Beck then noted that the Maintenance Agreements were on "hold" until the questions concerning the insurance provisions,identified at the previous Operating Committee,were resolved.He stated that the Transmission Service Agreement would probably be brought beforetheMatanuskaElectricAssociation(MEA)Board of Directors for discussion and approval at their next meeting in June.Finally,he stated that copies of these agreements were mailed to the Operating Committee members. Discussion then turned to the need for monthly accounting statements from the Power Authority.Harry Beck stated that he felt that the Budget Subcommittee should meet to help APA to develop the format for these reports.John Cooley said that this information on billings, energy usage,etc.could be shown in spreadsheet fashion. Finally,Marvin Riddle reported that Dan Homer from General Electric had completed his work on SVS Modifications at all 3 substations.He indicated that the voltage relays (i.e.SVS overvoltage trips)had been reset but that he did not know the new settings.Marvin Riddle stated that he could now perform a startup of the Healy SVS with a controlled bus voltage of 150 kV without getting an overvoltage trip of the SVS.Harry Beck indicated that he would make Don Homer's field report available when he received it. John Cooley then distributed draft copies of the manual,"Alaska Intertie Operating Committee."This manual is the updated record of all formal actions and adoptions of guidelines taken by the Operating Committee.John Cooley requested that the manual be thoroughly reviewed prior to their being accepted as the final version.John Cooley then stated that the Operating Committee had received correspondence since the previous meeting.He then described the nature of the correspondence.See attached. 4620/558(3) 34 Alaska Intertie erating Committee Meev.ag May 21,1986 Page 4 There were no visitors present at the meeting. Under Old Business,Ed Morris asked if the members were satisfied with the degree of detail being presented in the Minutes of the Operating Committee.John Marshall stated that in his opinion,these minutes have been excellent and that they are the best set of Minutes developed since the inception of the Operating Committee.Ed Morris then polled the members as to their feelings on having the Operating Committee meetings recorded in the event of disputes between the Minutes and members'recollections.The consensus of the Committee was that recording the sessions would be acceptable. Under New Business,Marvin Riddle indicated that the Dispatch/Scheduling Subcommittee may need to conduct another special session concerning the proposed testing of the SVS.Harry Beck indicated that the Power Authority is waiting for Commonwealth Associates to reply to the test plan review letter sent them by Morrison-Knudsen.He further stated that once this replay is received,then the APA will contact the Chairman of the Dispatch/Scheduling Subcommittee (i.e.Marvin Riddle)to discuss the need for another subcommittee meeting. Discussion then turned to insurance.Marvin Riddle expressed his concern that the State only carries insurance on the substations and their equipment and that the transmission line itself is not insured. Ed Morris confirmed that statement adding that insurance for transmission lines is not available at reasonable costs.He further stated that the State had not yet received the insurance costs for FY87.John Spence then requested that the Power Authority furnish the Participants with a brief report on the entire insurance Situation:what is and is not available,what is the exposure,what is the cost and so on.Ed Morris explained that the Division of Risk Management was presently preparing just such a report. Discussion then covered the R&R fund and its relation to the insurance questions.John Spence suggested that the R&R fund should be addressed in the Power Authority's report on insurance.He further indicated that the General Managers of the utilities will ultimately have to respond on this entire issue.Ed Morris suggestedthattheOperatingCommitteedealwiththisissue(i.e.R&R fund) first as the General Managers,in responding to the insurance report,would likely consult their Committee representatives anyway. Discussion of insurance finally concluded with the topic of self-insurance.Ed Morris stated that the letter ML&P had submitted to the Power Authority in the way of proof of adequate self-insurance coverage was inadequate.The language contained in the Alaska Intertie Agreement dealing with self-insurance was then reviewed by the Committee.John Spence then concluded that the City ofAnchorage's self-insurance provisions (see attached)do not meet the 4620/558(4) Alaska Intertie erating Committee Mee..ng May 21,1986 Page 5 provisions of the Agreement.Sam Mathews commented that the Agreement may need to be revised or amended because of the insurance issue.Finally,John Spence indicated that the issue or self-insurance should also be addressed by the Power Authority in their report on insurance. Under FY87 Budget,Ed Morris asked if it made any sense to spend a considerable amount of time refining the budget package as the previously submitted estimate (i.e.$1,763,755)was most likely within 10%of what will ultimately be the final budget amount.John Spence indicated that he would still like to review ML&P's breakdown of their overhead costs when it's available.John Cooley replied that this information had been transmitted to all parties on May 12, 1986. It was proposed that the Operating Committee adjourn for a short break.The Operating Committee recessed for break at 11:55 a.m. The Operating Committee reconvened at 12:05 p.m.. Continuing under FY87 Budget,Ed Morris read the April 24,1986 letter from John Spence of Chugach Electric Association to Ed MorrisoftheAlaskaPowerAuthority(attached).Replying to this letter, Ed Morris stated that he had received all of the information from the respective Participants (requested by John Spence in his letter) except that from MEA.Jim Hall promised to ask his General Manager to provide the requested information.Discussion then centered on the fact that standard accounting procedures for the capitalizationoftoolsandequipment(i.e.maintenance activities)have not been developed and reviewed by the Operating Committee.John Spence suggested that this process be established soon.Discussion on FY87 Budget concluded with John Cooley's statement that this budget is in effect already and that the APA should complete their preparation ofthefinalbudgetpackage(FY87)and submit it for review by the General Managers. Turning to MITCR,John Cooley distributed copies of the FY87 MITCR calculation worksheet with attachments and requested that the members review and comment prior to subsequent adoption of the FY87 MITCR under formal Committee action.John Marshall concluded that there was not substantial change in the MITCR figures between FY86 and FY87. Under FY88 Budget,John Cooley distributed his projections for theOperatingCommitteecosts.Sam Mathews suggested including $15,000 for legal services.Jim Hall praised the Committee for holding the line on costs since the projected Operating Committee FY88 budget(attached)is identical to that for FY87 (i.e.$142,000). 4620/558(5) Alaska Intertie erating Committee Meeving May 21,1986 Page 6 At 12:30 p.m.,under formal Operating Committee action,Chairman John Cooley entertained a motion for adoption of the FY87 MITCR.Sam Mathews so moved.The motion was seconded by Larry Colp and was approved unanimously. Chairman John Cooley then entertained a motion for adoption of the Operating Committee Budget for FY88.Sam Mathews so moved. The motion was seconded by John Marshall and was approved unanimously. The Chairman then directed the RELIABILITY SUBCOMMITTEE TO MEET ON WEDNESDAY,JUNE 4,1986 AT 10:00 A.M.AT CHUGACH ELECTRIC ASSOCIATION for the purposes of reviewing the remaining study proposals from UAF on System Analyses and Geomagnetic Disturbances and to develop specifications for them. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. A Special Subcommittee on Billings/Accounting was then established. The members designated for this subcommittee were John Cooley,Bob Orr,Harry Beck and John Spence.Chairman John Cooley then directed the SPECIAL SUBCOMMITTEE ON BILLINGS/ACCOUNTING TO MEET ON WEDNESDAY, JUNE 11,1986 AT 9:00 A.M.IN THE EXECUTIVE CONFERENCE ROOM AT THE ALASKA POWER AUTHORITY in conjunction with the Accounting Department of the Power Authority to develop procedures for the reporting of revenues and expenditures associated with Intertie operation and maintenance. Larry Colp then motioned for the meeting to adjourn.Marvin Riddle seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 12:45 p.m.. Respectfully submitted, aya L.Morris,Secretary Alaska Intertie Operating Committee ELM/HB:kyf Attachments: 1.July meeting agenda 2.Minutes from May 8,1986 Dispatch/Scheduling Subcommittee Meeting w/attachments 3.Data Base Management Agreement Between University of Alaska-Fairbanks and Alaska Intertie Operating Committee 4620/558(6) Alaska Intertie erating Committee Meer..g May 21,1986 Page 7 >Chugach Electric Association letter to Alaska Power Authority dated April 24,1986 University of Alaska-Fairbanks letter to Reliability Subcommittee dated May 7,1986 Alaska Intertie Operating Committee FY88 Budget FY87 MITCR Calculation Worksheet w/attachments Attendance list from May 21,1986 Intertie Operating Committee meetingLetter from Alaska Power Authority to Intertie Operating Committee dated May 20,1986 10.Letter from Alaska Power Authority to Golden Valley Electric Association dated May 19,1986 11.Letter from Municipality of Anchorage to Alaska Power Authority dated May 6,1986 w/attachments.ive)onoone°eee4620/558(7) DISPATCH SCHEDULING SUBCOMMITTEE MAY 8,1986 The dispatch scheduling subcommittee held a special meeting requested by APA to formulate plans for testing the Intertie.ThemeetingwasheldatAML&P and was convened at 0900 here. Those in attendance were: Marvin Riddle GVEA Ernie Jameson MEA Thomas B.Hite MEA Doug Hall AML&P Ray Duncan CEA Glenn Davis CEA Lee C.Warnock M.K. John Stafford APA The meeting was called to order by Marvin Riddle,chairman. The subcommittee discussed the proposed test plan -copy attached. The discussions and comments of the test plan are by general headings. Before taking verbal comments,Marvin distributed GVEA's written responses (copy attached)and explained each of them. 1.ENERGIZATION Track and measure system unbalances.See GVEA written comments - include steady state voltage each phase 3.(n)AMNL&P does not have enough SCADA indications coming back to accomplish this step.AML&P asked the engineer to clarify if they wanted to use Teeland 538 or 4710 for this portion.Doug Hall will submit in writing once he has a handle on his concerns at Teeland. (What it will take) Need to address the Douglas high voltage problem during testing.MEA Ernie Jameson says he will take a distribution outage while this testing is occurring.He would like a 3 day alert so he can notify his customers., Need to have APA give us a rating on the motor operated switches - 1.e.load break,charging load break,no load break-at Douglas and Cantwell.This has been requested before,but no answer has been received from APA. MEA also intends to monitor voltages at Douglas while testing is occurring,especially when trying to start Teeland SVS from North. Specific questions on Douglas motor operated switch to drop Teeland to Douglas 138 KW line by Ernie Jameson would simplify operation if this is possible. Seems to be a problem on what's provided as far as synchronizing - control and indication at Teeland,CEA,and AML&P.Will investigate and respond to APA on what additional is required. The outages and testing will all occur during normal working hours 0800-1700 -weekdays. 2.DE-ENERGIZATION Measurements:Add at all (3)locations Recommendations:Engineer should define in more detail the following Statement:Test should occur during a minimum system generating condition to be most demanding.AML&P expressed concerns about E-stop on SVS's,what is meant by most demanding,is power flowing, what quantity and what direction.Needs engineers explanation of what he is trying to accomplish with the test.Concern on capacity of system to absorb or generate VARS if in minimum generation configuration. While Don Homer is here,he needs to calibrate voltage.Set vs. regulated voltage.(Marvin stated this is still not correct. 3.POWER TRANSFER How long is each portion of each test,one hour?Utilities would like minimum of one hour,maximum of ?. Shipping the full 70 MW required North is probably not achievable on FMUS/GVEA system this time of year. Could probably test full 70 MW South and some lesser quantity North 35-50 MW.If it appears to be a problem or APA,or utilities want to test 70 MW North.Reschedule this part of test for later in year when loads are high.Summer is good time to test if something fails because systems are not going into peaks. 4.SVS RESPONSE Utilities feel these tests should be integrated so the SVS responses can be more appropriately scheduled with maximum and minimum power transfers and all ranges in between this will give best voltage profiles for entire system. Utilities would like to see stepped tripping start at a low value and work up to the 40 MW to gather good base line data at different points. Need direction of power flows defined. Engineer feels it will take approximately one week to complete all testing required. Page 3 5.HARMONIES No comments on this Section of the test. 6.SVS LOSS TEST APA stated they did not feel a need to run this test.GVEA has nocommentsonwaytestisperformed,but they think it is required so the amount of losses on the SVS's are known to determine if there are any changes in operating modes required,also to see if they Meet specifications. CEA commented on who by contract had to absorb the losses generated by the SVS's. New Heading Added: 7.'FINANCIAL CONSIDERATION Marvin asked that the engineer provide a total manpower requirement, what APA (GE)would provide,what they expected the utilities to provide. The costs of the manpower required,the additional cost of committing-decommitting units needs to be addressed.What is APA Willing to adsorb as far as costs? a[ey GOLDEN VALLEY ELECTRIC ASSOCIATION ING.Gox 1249,Farbanks,Alaska 99707 Phone SO7-452-1151Gy May 5,1986 Harry L.Beck Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 Subject:Alaska Intertie Testing Dear Harry: The following are comments GVEA has pertaining to your proposed test Plan,which are attached. Type of test:Energization (Page 1 of detailed test) Please add the following measurements: System Steady State Voltage (including each phase voltage) Under the heading "Recommendations": 1.Add --(e)Measure source end and receiving end, 3 phase voltage unbalance Change (e)to (£)Synchronize systems at Healy 2.Add -(e)Measure source end and receiving end, 3 phase voltage unbalance Change (e)to (f£)Synchronize systems at Douglas 3.Add -(h)Measure source end and receiving end, 3 phase voltage unbalance Change (h)to (i)Synchronize systems by closing Teeland 230 KV breaker Type of Test:Power Transfer Capability Under the heading "Recommendations”: Add -3)Note each phase voltage at Gold Hill,Healy,Douglas,andTeeland,throughout these tests at zero,1/4,1/2,and full load levels,both directions.The purpose of this data is to determine if the phase voltage imbalance is within acceptable levels. Ly - GOLOEN VALLEY ELECTRIC ASSOCIATION INC. »? -_ Page 2 Alaska Intertie Test Type of test:SVS Response Under the heading "Recommendations”: l.Changeto réad:Perform slope control test at several voltage set points at Teeland,Healy,and Gold Hill. Record actual bus voltage,actual SVS VAR flows and set point selected to determine if the SVS's are regulating on the %slope selected as designed -2%and 5%slope characteristics should be checked. GVEA feels this is a good test plan.With these few minor changes we feel it would adequately test the Alaska Intertie. It is assumed that this performance test plan is Phase I of the project.GVEA envisions the following course of events which must happen to actually perform the tests in the field. Phase I -Define what should be tested.Preliminary Performance Test Plan. Phase II -Establish what of Phase I can be accomplished (is feasible)within reasonable abilities of the utilities systems. Phase III -Define procedures and schedule to accomplish Phase II. Phase IV -Define excess costs associated with Phase III and who shall bear this cost. Phase V -Perform field test as determined above and obtain results. Phase VI -Evaluate results of Phase V and prepare a report of findings to be distributed. With the comments of Phase I complete,I recommend the Dispatch Scheduling Subcommittee meet to attempt to complete Phase MII.An initial meeting has been called by the chairman of the Subcommittee for Thursday,May 8,1986 at AML&P Engineering Conference Room. Subsequent meetings will be needed to complete Phase II and Phase III by this Subcommittee.These meetings should have APA and CAI representation. Ct .rvin Riddle ystem Dispatch Supt. cc:J.Huber -GVEA J.Cooley -AML&P M.Kelly -GVEA R.Duncan -CEA R.Orr -GVEA J.Stafford -APA q Gilbert /Commonwealth engineers and consultantsGILBERTCOMMONWEALTHINC.OF MICHIGAN,209 E.Washington Avenue,Jackson,Mi 49201/Tel,$17 788-3000 April 18,1986 APAI-10640 Mr.Lee C.Warnock Contract Administrator Morrison-Knudsen Company,Inc.813 D Street Anchorage,AK 99501 Dear Mr.Warnock: SUBJECT:ALASKA POWER AUTHORITY ANCHORACE-FAIRBANKS INTERTIE PROJECT PERFORMANCE TESTING This letter is in response to a March17,1986,GE letter related to testing programs and an April7,1986,conversation between A.Khan (APA)and S.W.Arnold (G/C),Ms.Khan had requested G/C to provide APA with intertieperformancetestingrecommendations.We have identified six different categories*of tests of which are applicable to the intertie,namely: 1.Energization , 2.De-energization 3.Power Transfer Capability 4.SVS Voltage Response 5.Harmonie 6.Loss Testing . 7,Fintedie tet Ads layeti ie Numerous tests could be performed in each category,however,we have attemptedtolimitthetotalnumberoftestsandconsequently,the amount of time and costrequiredtooerformthetests,Cue annenach fe to aantite sad annem ee Tost ees oo Lice get retewes peule ate ebbegeiey Of Wie intertie,out at ihe same time,moderating the test severity.; Attached to this letter are detailed discriptions of each test category.We haveoutlinedeachcategorybythetypeoftest,its objectives,the acceptance criteria,&discussion and our recommendations for testing.: :a" Other areas,related to performance testings,which should be considered at thistimeinclude:1)the final disposition of the performance testing results,2)thenumberoftestteamsoperatingsimultaneouslyduringthetesting,and 3)the meansnecessarytoplan,organize,and perform the testing.We assume a formalizedPerformanceTestReport"will be generated at the conclusion of the testing.ThebenefitsofhavingthreetestteamsoperatingsimultaneouslyateachSVSsiteneedstobecomparedtooneteamwhichmovesconsecutivelyfromsitetosite.ThreetestteamswouldallowoscillographmeasurementsateachSVSlocationforeach £25 Loncaster Averace,Resenag,PA/Morgantown Read,Groen hulls,Readeng,PA 295 775.2008 rR han w A Jack $0 T-Ov * ,'aotg Glibert/Commonwealth erent Bred Conventyeag Mr.Lee Warnock APIA-20640 April 16,1986 Page 2 switching operation.With only a single team,it would be necessary to repeatswitchingoperationsortoreducethequantityofinformationgathered.Finally, the time and effort required to develop a detailed test program in addition to that required to implement such @ program needs to be addressed. Note that our comments to G.E.'s March 17,1986,pertaining to loss testing will be covered under a separate letter.We trust this letter will aid you further In finalizing the performance testing program. Sincerely, ws!a ) a L.G.Miller,P.E. Project Manager SWA/pIm Enclosure ee:'D.Eberele APA -w/encl A.Khan APA -w/encl. TYPE OF TEST:Energization OBJECTIVE:Demonstrate that the intertie can be energized by any of thesequencesapprovedintheOperatingProcedures.Demonstrate that the intertle can be synchronized at Gold Hill,Healy,Douglas,and Teeland. ACCEPTANCE CRITERIA:Voltages are maintained within prescribed limits both.in magnitude and duration.Synchronizing systems are operational. MEASUREMENTS:System steady state voltages should be monitored and recorded as each segment of the intertie Is energized.The dynamic voltages at applicable points should be recorded by an oscillograph tracing.during the energization of alinesectionoraSVS. DISCUSSION:During the past year,the operating utilities have demonstrated that the intertie can be energized in different sequences.These include: 1.Energizing the transmission line between Douglas and Healy from Douglas; synchronizing at Healy. 2.Energizing from Healy and synchronizing at Douglas. 3.Energizing the transmission line between Gold Hil and Healy from Healy;:_synchronizing at Gold Hilt. .The system operating conditions during these initial SVS starts provide more than ample generation to minimize the voltage excursion resulting from SVS starts.WehaveyettodemonstrateSVSstartingwithminimumgenerationonline.Also,wehaveyettodemonstrateemergencyornon-standard ways to energize andsynchronizetheintertie.We suggest that the tests be performed which result in energizing the intertle In a non-standard way with minimal generation on line.OnesuchtestcoulddemonstratetheabilityoftheFairbankssystemtoenergizeandsupplypowertotheTeelandsubstation.If this test is attempted during the early'summer,minimum generation would be on line,thus demonstrating the ability toenergizetheintertieforweaksystemconditions.We also suggest starting theintertiebythenormalandalternatemethoddescribedintheoperatingprocedureswhilamonitoringandrecordingsystemcharacteristics. RECOMMENDATIONS: 1.Demonstrate and record the normal method of energizing the intertie. System condition prior to starting would be characterized by Independent Anchorage and Fairbanks systems,with all SVSs off. a.Start Gold Hill SVS. b.Start Teeland SVS. ¢.Reconfigure line:section between Healy,Cantwell,and Douglas. Energize line between Douglas and Healy from Douglas. -82MAP A-PF/D27 2. 3. d. es Start Healy SVS on line from Douglas. Synchronize systems at Healy. Demonstrate and record the alternate method of energizing the intertie.System condition should be the same as number 1 above.. a. b. Ce d. Start Gold Hill SVS. Start Teeland SVS. Start Healy SVS on Healy transfer bus. Reconfigure line section between Healy,Cantwell,and Douglas. Energize line between Douglas and Healy from Healy. Synchronize systems st Douglas. Demonstrate and record the energization of the intertie from the Fairbankssystemsduringaminimumgenerationcondition. a. b. Cc. d.- Energize Gold Hill S¥S. Energize Healy SVS ca Healy transfer bus. -Reconfigure line between Healy and Douglas.Energize line between Healy and Douglas {rem Healy. De-energize line be:ween Douglas and Teeland 230 kV by opening Teeland 230 kV breaker and 138 kV breaker.' Pnergize line from Douglas to Teeland. Energize SVS switchgear by closing Teeland 138 kV breaker.4 TEs osE-Ure do Taee ohStartTeelandSVSonZairbankssystem. Synchronize systems sy closing Teeland 230 kV breaker,S220 G4 Ta ™.mo 'l=;--Dele 8s Ne Yar ee Peavy'@ "wed ween s,ne -of ha,/a "ALi adg:Leaihed -ud aorpeek a dnc LA vhowi One CadeelWyliegee(ed mek B daw ows ) _DABS Ceere AL WO OES ba a, :..o ..fr i Fe PRey yfjadSyee"pr UAT )¢XQ =ao. .A .imme). er On er st prucing rréu 62/(4)APA-PF/D27 . TYPE OF TEST:De-energization OBJECTIVE:Demonstrate that the intertie and SVS can be de-energized without.resulting equipment damage or system misoperations. ACCEPTANCE CRITERIA:No equipment failures or misoperations should result from the de-energization of individual segments of the intertie. MEASUREMENTS:SVS voltages and currents should be monitored and recorded with an oscillograph tracing during the de-energization of specific intertie com-ponents,AT Me @ Locatos DISCUSSION:The major concern during de-energization of the intertie (specifi- cally the SVS)is the failure of thyristors.Thyristor fallures have occurred exclusively at Gold Hill and Healy and only during emergency shutdowns originating in SVS controller or by manual emergency stops.The failure mechanism has been identified and a solution offered by G.E.After G.E.has implemented the control system modifications,the SVSs will be de-energized numerous times to prove the fix.It appears that SVS's operating on weak systems were more susceptible tothyristorfailure.Therefore,we suggest testing allSVSs,including Teeland,while.operatingthePairbankssystem.The test at Teeland could be accomplished inconjunctionwiththeenergizationtestspreviouslyrecommended. C RECOMMENDATIONS: 1.Test the ability of all SVSs to be de-energized numerous times via an emergency stop command without sustaining thyristor failure.Test shouldoccurduringaminimumsystemgeneratingconditiontobemostdemanding. ee .-. Con trcns,Ne ewe "Tths in Taave kote \ S2/(S)APA-PP/D27 TYPE OF TEST:Power Transfer Capability OBJECTIVE:Demonstrate the power transfer capability of the intertle as compared to the design criteria. ACCEPTANCE CRITERIA:With all SVSs operational,the transfer capabilitybetweenHealyandTeeland,at the receiving end,shall be at least 70 MW. Ta Me PeterMEASUREMENTS:System voltages,real and reactive power flows along the-intertle should be monitored and recorded.== DISCUSSION:Power transfer capability testing should be attempted only after the230kVlinkbetweenTeelandandPt.Mackenzie has been placed in service. Demonstration of 70 MW transfer capability from south to north will be dependent upon Fairbanks load at the time of testing.However,testing the power transfer capability from north to south could be accomplished.. RECOMMENDATIONS: 1.Transfer 70 MW (or as much as possible)from north to south.Monitor and record Intertie voltages,reactive and real power flows at Teeland,Dougias, Healy and Gold Hill.Also monitor and record additional VAR support provided by local Fairbanks generation. 2.°Transfer 70 MW (or as much as possible)from south to north.Monitor and record intertie voltages,reactive and real power flows at Teeland,Douglas, Healy and Gold Hill Also monitor and record additional VAR support provided by local Fairbanks generation.WSue Corre2S on ¢Vito We oH caneidle nevis "hreflte thet ans Darien de te Ch Seta 4 DNF neers ag AO oo _- am 4 4).-Cut Hiawde gab 62/(6)APA-PP/D27 "nage TYPE OF TEST:SVS Response OBJECTIVE:Demonstrate the control response of the SVS during normal andabnormaloperatingconditions. ACCEPTANCE CRITERIA:Power system responses shall be in accordance with the results of dynamic stability studies as contained in paragraph 2.1.3, pages 31-33,of the Operating Procedures. MEASUREMENTS:Steady state and dynamic voltages,real power flow and reactive power flows should be monitored and recorded. DISCUSSION:The design parameter which we suggested be checked include: 1)SVS slope control;2)SVS control systems'stability;and 3)intertie performance during SVS tripping.The SVS slope selection controls the voltage regulation band width We suggest that the various slope selection settings be tested to demonstrate conformance with the specifiction.The power system was modeled to select SVS control systems gain and time delay values.The critical system condition includes all SVSs operating exclusively on the Fairbanks systems.We suggest operating in this mode to demonstrate inter-related control system Stability of the three SVSs.Dynamic stability and power flow studies have shown that the loss of a single SVS during heavy intertie loading does not result In dynamic Instability or excessively low voltages.We suggest demonstrating the capability of the intertie to tolerate the tripping of an SVS while loaded. RECOMMENDATIONS: 1.Perform slope control test at Teeland,Healy,and Gold Hill., 2.Demonstrate SVS control system stability under weak system condition. Start and operate all SVS while connected to only the Fairbanks system. 3.Demonstrate power system stability and SVS voltage control by selectivelytrippingoutSVSsduringintertleoperation. a.Trip Gold Hill SVS at an intertie loading of 40 MW. oN x,re ub -b.Trip Teeland SVS at an intertie loading of 40 MW.>ON'T ° il Ee)/Hdenn [Bs na Come 62/(7)APA-PF/D27 -gf Els asTYPE OF TEST:Harmonic Measurements OBJECTIVE:Demonstrate that the harmonic voltage distortions produced by theSVSsarewithinspecifiedlimits. ACCEPTANCE CRITERIA:Harmonie content shall be in accordance with para- graph 1.3.2,page 6.2.3,of Procurement Contract No.APA-83-C-0051 for static VAR systems. "The harmonic voltage distortion on the 69 kV and 138 kV buses;caused by the SVS operating anywhere within its steady state rating,shall have an RMS total of all harmonics through the 25th of less than 1.5 percent of the fundamental." MEASUREMENTS:Harmonic magnitude and content would be measured and plotted for power system voltages and currents at different SVS operating points. DISCUSSION:Harmonic measurements sould be performed to demonstrate SVS conformance with the specification.Measurements would be taken at various SVS operating points during intertie operation or on islanded north and south systems. RECOMMENDATIONS: 1.Perform harmonic voltage and current measurements at Gold Hill,Healy,and *Teeland at various SVS load points. 62/(8)APA-PF/D27 TYPE OF TEST:SVS Loss Testing OBJECTIVE:Determine the actual energy losses for each SVS. "ACCEPTANCE CRITERIA:Losses are contractually listed at various operatingpointsforeachSVS.Price adjustments are contractually specified if the SVS exceeds 'guaranteed losses.Method of calculating the price adjustment is pre- "sented In paragraph 5.13.0,page 5-13,of the SVS procurement contract. MEASUREMENTS:Monitor and record each SVSa'losses at specific SVS operating points.A special test circult is required to obtain highly accurate results. DISCUSSION:Evaluation of quoted losses was part of the SVS manufacturer selection process.In order to substantiate the bidders quotes losses,the specifica- tion required that the successful bidder measure the SVS losses at Teeland,Healy, and Gold Hil);thus proving the efficiency of the systems. RECOMMENDATIONS: 1."Perform loss test at Teeland,Healy,and Gold Hill in accordance with the specification. yidb&tin A$5ud cond rtet eneShkameRew"Loney Pe af g N °1)ody ™Leys tte 42 me Ae DATA BASE MANAGEMENT AGREEMENT BETWEEN UNIVERSITY OF ALASKA-FAIRBANKS AND ALASKA INTERTIE OPERATING COMMITTEE This agreement Chereinafter referred to as Agreement)is made and entered this ______._day of __»1986 by and between the University of Alaska-Fairbanks and the Alaska Intertie Operating Committee. IN WITNESS WHEREOF,the signatories to this Agreement, consisting of (1)Signature Page,(2)Specifications For Data Base Management,and (3)University of Alaska- Fairbanks Proposal,"Alaska Intertie And Data Base Management",have caused this Agreement to be executed in duplicate by their duly authorized officers or representatives as of the day and year first above written. UNIVERSITY OF ALASKA-FALIRBANKS ALASKA INTERTIE OPERATING COMMITTEE SPECIFICATIONS FOR DATA BASE MANAGEMENT I.WORK INCLUDED A.SCOPE OF WORK 1.The Work comprises the completion of all tasks identified in the Contract.These tasks involve the management and periodic updating of the Master &Utility Data Bases. B.CHANGES IN THE WORK 1.Owner,without invalidating the Contract,may order Changes in the Work consisting of additions,deletions,or modifications,the Contract Sum and Schedules being adjusted accordingly. 2.Changes in the Work shall be authorized by written Change Order signed by the Owner and Engineer. 3.Contract Sum may be changed only by Change Order. .4.Cost or credit to Owner from a Change in the Work shall be determined by mutual agreement between Engineer and Owner. II.RESPONSIBILITIES OF PARTIES A.ENGINEER 1.Engineer shall submit to Owner in writing al] requests for information and data relevant to the Work. 2.Engineer shall provide Owner with written progress reports concerning the completion of the Work consistent with the Contract Schedules. 3.Engineer will ensure that only Engineer has access ta the Master Data Base for editing purposes. 4.Engineer will take all reasonable measures to ensure that the Master Data Base is not changed or modified except as provided for in performing the requirements af the Contract. 5.Engineer will take all measures necessary to ensure that the Master Data Base and the Utility Data Bases are not damaged or lost or otherwise rendered inoperative for the purposes for which they are to be utilized.Safeguarding of the Master Data Base and the Utility Data Bases is an essential element of this Contract. 6»Engineer shall provide Utility with full access (i.e.file read &write permissions)to the Utility Data Base and limited access (i.e.file read permission only)to the Master Data Base through the University of Alaska Computer Network CUACN). 7.Engineer will perform one power flow and stability case computer analysis at each instance of Master Data Base updating to ensure that the data being submitted is cansistent with the data entry requirements of the power flow and stability analysis programs. B.OWNER 1.Owner shall provide to Engineer all information and data relevant to the Work in a form and manner as specified by Engineer. 2.Qwner shall submit all information and data toa Engineer in a timely manner consistent with the Contract Schedules. 3.Owner shall review all progress reports submitted by Engineer and shall notify Engineer in writing of the results af these reviews.These reviews will be provided to Engineer in a timely manner consistent with the Contract Schedules. 4.Owner shall notify Engineer in writing of all requests for updating and upgrading of the Master Data Base. Updating and upgrading of the Master Data Base will be performed at least annually.Owner's request for updating and upgrading of the Master Data Base shall constitute a Notice to Proceed for performing these tasks. C.UTILITY 1.Utility shall provide to Owner all information and data relevant to the Utility Data Base in a form and manner as specified by Owner. 2.Utility is solely responsible for the adequacy and accuracy of all data and information provided to Owner.Utility shall submit all information and data to Owner in a timely manner consistent with the Contract Schedules. 3.Utility will provide Owner with updates to Utility Data Base when so directed by Owner. 4.Utility shall review all progress reports submitted by Engineer as they relate to the Utility Data Base. Utility shall notify Owner in writing of the results of these reviews. S-Utility shall have sole proprietorship of and responsibility for the Utility Data Base.Access to and use of the Utility Data Base is subject to the written approval of Utility.Utility will take all measures necessary to ensure that the Utility Data Base is not damaged or lost or otherwise rendered inoperative for the purposes for which it is to be utilized. IIIl.SUBMITTALS A.SUBMITTALS 1.Engineer submittals include requests for Utility Data Base information and data,progress reports and data base revisions. 2.QOuwner submittals include progress report reviews, Utility Data Base information and data,Changes to the Contract Schedules and Changes to the Work. IV.SCHEDULES A.TIME 1.Time of commencement of Contract is the date as specified below by the Signatories of this document. 2.Date of Completion of the Work is the date certified by Owner when the Work is fully complete so that Ouner can utilize the Work for the use for which it is intended. 3.All time limits stated in the Proposal are of the essence of the Contract.If Engineer is delayed at any time in the progress of the Work by Changes ordered in.the Work, conditions not reasonably expectable,causes beyond the Engineer's control,failure of Owner to comply with responsibilities of Owner under this Contract,or by other cause which Owner determines may justify the delay,then Contract Schedules may be modified and Contract Time may be extended.If Engineer determines that a delay of this nature has occurred and that it warrants a change to the Contract Sum,then Engineer shall request in writing that Owner issue a Change Order authorizing Changes in the Work. 4.Contract Schedules may be changed or modified by mutual agreement. V.PAYMENTS A.CONTRACT SUM 1.The Owner shall pay Engineer for performance of the Work,subject to additions and deductions by Change Order, the Contract Sum of Forty Eight Thousand Six Hundred And Fourteen Dollars ($48,614). 2-The Contract Sum is determined as specified in the Proposal. B.PROGRESS PAYMENTS 1.Based upon applications for Payment submitted to the Owner by Engineer,Owner shall make progress payments to the Engineer.Ninety (90%)of the amount due shall be paid by Owner to Engineer within thirty (30)days after submission of the application for Payment. 2.Approval of the Application for Payment by Owner shall be issued following approval by OQuner of Engineer's progress reports. C.FINAL PAYMENT 1.Final payment,constituting the entire unpaid balance of the Contract Sum (i.e.the remaining 10%of the Contract Sum),shall be paid by Owner to Engineer when the Work has been completed and the Contract fully performed. VI.DEFINITIONS A.DEFINITIONS Contract -The documents constituting the entire agreement between Owner and Engineer,except for modifications, which are the Signature Page,this Specification and the Proposal to which it applies. Engineer --The Institute of Northern Engineering of the University of Alaska-Fairbanks. Master Data Base - The composite Utility Data Bases describing the interconnected Anchorage-Fairbanks electrical network.The initial Master Data Base is the interconnected system data base developed for the University of Alaska- Fairbanks final report (revised),"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. Owner -The Intertie Operating Committee.The function and authority of Owner in its relationship to Utility is defined in the Alaska Intertie Agreement. Proposal.-The proposal from the University of Alaska-Fairbanks to the Intertie Operating Committee,"System Data Base Management"dated March 1986. Utility -Any ane of the utilities maintaining a Utility Data Base as a subset of the master data base at UACN. Utility Data Base -The detailed information and data describing the utility system in a computer structured format residing in the Master Data Base at UACN.The initial Utility Data Base is the individual utility data base developed for the University of Alaska-Fairbanks final report (revised), "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System",dated November 1985. SE.86.48 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE ALASKA INTERTIE AND DATA BASE MANAGEMENT by Institute of Northern Engineering University of Alaska-Fairbanks Fairbanks,Alaska 99775-1760 March 1986 .Loca Ae hi. nD.Aspnes ft T.D.Roberts,DirectorPrincipalInvestigatorInstituteofNorthern Engineering Geor A ip Wins Chancellgr folCo-Investigator WO intversit Alaska-Fairbanks INTRODUCTION This proposal requests continuing support for management and update of a data base developed under a previous proposal titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System." The dynamic stability study proposal was funded by Anchorage Municipal Light and Power (AMLP),Chugach Electric Association,Inc.(CEA), Fairbanks Municipal Utilities System (FMUS)and Golden Valley Electric Association,Inc.(GVEA).The stability study data base,structured to support the Electric Power Research Institute (EPRI)745 transient- midterm stability program,resides with the 745 code in the University of Alaska computer network (UACN).The four utilities named above and the Alaska Power Authority (APA)have access to this data base and stability program.The Alaska Intertie Operating Committee has indicated an interest in having the data base updated and having electric power system stability studies performed using the revised data base. PROJECT JUSTIFICATION This proposed project takes advantage of tasks completed under the previous proposal titled "Dynamic Stability Study of the Anchorage- Fairbanks Interconnected Power System."These tasks included assembling a data base for the interconnected Anchorage-Fairbanks electric power systems to be used with the Electric Power Research Institute (EPRI)745 Transient-midterm Stability Program.Five case studies were performed, using the EPRI 745 code.Results are given in the project final report. The resulting data base modeling the Alaska intertie,and the electric power systems it interconnects,resides on the UACN computer network along with a working copy of the EPRI 745 code.The four participating utilities and the APA have access to this data base and EPRI software. Managing and upgrading the data base will help participating utilities obtain the most from their investment in the previous project. In addition,this project,like the previous one,is an investment in educating future power engineers for the Alaskan utility industry. PROJECT SCOPE Project tasks to be performed include: 1.Manage and update the data base currently residing on the UACN computer.This includes making changes to the master copy of the data base at least annually,using data supplied by each utility. Also,one power flow and stability analysis case will be run with the revised data to ensure that the modified data base is an acceptable input to the computer programs. As in the recently completed project,each participating utility will have access to the master data base from its own account but will not be able to directly modify it.Individual user account charges from UACN are the responsibility of each utility PROJECT SCHEDULE Timetable Tasks June 1986 -October 1987 Update and review system data base; verify new data base works with computer programs.These tasks will be performed at least twice during the contract period,with one revision to be completed by October 13,1986 and a second revision to be completed by October 31,1987.This schedule assumes revised data base information will be received from all participating utilities by July 15, 1986 and,for the second revision, July 15,1987. BUDGET 1 July 1986 -30 September 1987 SALARIES 1.Principal Investigator,J.Aspnes4wks@$36.06/hr 2.Principal Investigator,G.Mulligan 4 wks @ $28.84/hr 3.Graduate Research Students 1200 hrs @ $10.00/hr LEAVE BENEFITS 1.16.1%of A.1 and A.2 STAFF BENEFITS 1.24.6%of A.1,A.2 and B.1 TRAVEL 1.Travel between arenes andFairbanks(20 trips @ $250) SERVICES 1.Documentation and reports 2.Telephone 3.Computer support SUPPLIES 1.Photocopy and expendables 2.Magnetic tape OVERHEAD 1.39.2%of MTDC (items A through F) FY TOTAL PROJECT TOTAL FY87 FY88 $2,885 $2,885 2,308 2,308 6,000 6,000 836 836 1,483 1,483 2,900 2,500 400 400 250 250 350 350 350 350 100 100 6,845 6,845 $24,307 $24,307 $48,614 -JOHN D.ASPNES -Biographical Sketch ADDRESS: Department of Electrical Engineering,Institute of NorthernEngineering,University of Alaska,Fairbanks,AK 99775.Phone:(907) 6098. EDUCATION: B.S.Electrical Engineering (Univ.of Wisconsin)1963;M.S.Electrical Engineering tuniv.of Wisconsin)1965;Ph.D.ElectricalEngineering(Montana State Univ.)1976. PROFESSIONAL EXPERIENCE: 198l-present Professor;1978-81 Associate Professor;1976-78 Assistant Professor;1967-76 Associate Professor;1965-67 Associate Engineer;1965-65 Project Assistant;1963-64 Associate Engineer. PROFESSIONAL ORGANIZATIONS: Institute of Electrical and Electronics Engineers,IEEE Power Engineering Society,IEEE Education Society,IEEE Industrial Electronics and Control Instrumentation Society,IEEE Industry Applications Society, American Society of Engineering Education. RESEARCH INTERESTS: Electric power transmission,solar heating PUBLICATIONS: Aspnes,J.D.,B.W.Evans,and R.P.Merritt.1984.Rural Alaska electric power quality.Accepted for presentation at the July 1984 IEEE Power Engineering Society Meeting and publication in the IEEE Transactions on Power Apparatus and Systems. Aspnes,J.D.,B.W.Evans,and R.P.Merritt.1983.Rural facility electric power quality analysis.Alaska Science Conference. Aspnes,J.D.,and R.P.Merritt.1983.Effect of DC excitation on instrument transformers.IEEE Transactions on Power Apparatus and Systems.Vol.PAS-102,No.11.pp.3706-3712. Zarling,J.P.,and J.D.Aspnes.1983.Low-grade geothermal energy conversion by organic Rankine cycle turbine-generator.Proceedings of the 18th Intersociety Energy Conversion Engineering Conference. 1:294-299, Akasofu,S.-I.,and Aspnes,J.D.1982.Auroral effects on powertransmissionlinesystems.Nature.Vol.295,No.5845. pp.136-137. Aspnes,J.D..1982.-Electric power generation from a geothermal sourceutilizingalow-temperature organic Rankine cycle turbine. Presented at IEEE Power Engineering Society Meeting,San Francisco, CA. Aspnes,J.D.1982.Invited discussion of IEEE paper No.81 SM 338-3. Characteristics of geomagnetically induced currents in the B.C. hydro 500 kV system.IEEE Transactions on Power Apparatus and systems.Vol.PAS-101,No.6.pp.1455. Aspnes,J.D.,and Akasofu,S.-I.1982.Effect of solar induced current on autotransformer tertiary windings.IEEE Transactions on Power Apparatus and Systems.Vol.PAS-101,No.3.pp.635-638. Aspnes,J.D.,and J.P.Zarling.1982.A field evaluation of an ormat organic Rankine cycle turbine generator utilizing a low-grade geothermal/waste heat source -final report. Aspnes,J.0.,and J.P.Zarling.1982.Electric power generation from a geothermal source utilizing a low-temperature organic Rankine cycle turbine.IEEE Transactions on Power Apparatus and Systems.Vol. PAS-101,No.12.pp.4587-4592. Zarling,J.P.,and Aspnes,J.D.1982.Geothermal power generations using a low-temperature organic Rankine cycle turbine.Proceedings of the Symposium on Appropriate Energy Technology for Arctic Regions,33rd Alaska Science Conference,Fairbanks. Aspnes,J.D.1981.Effect of solar induced current on autotransformer tertiary windings.IEEE Power Engineering Society Meeting, Portland,OR. Aspnes,J.D.1981.Solar induced current affects power system components.Presented at Alaska Science Conference,Fairbanks. Aspnes,J.D.1981.Invited discussion of IEEE paper No.80 SM 646-0. Current transformer and relay performance in the presence of geomagnetically-induced currents.IEEE Transactions on Power Apparatus and Systems.Vol.PAS-100,No.3.pp.1087. Aspnes,J.0.,and S.-I.Akasofu.1981.Solar induced current affects power system components.Alaska Science Conference,Fairbanks. Aspnes,J.D.,and R.P.Merritt.1981.Invited discussion of IEEE paper No.F 79 694-1.Harmonics and switching transients in the presence of geomagnetically-induced currents.IEEE Transactions on PowerApparatusandSystems.Vol.PAS-100,No.2.pp.603. Aspnes,J.D.,and R.P.Merritt.1981.Invited discussion of IEEE paper No.F 79 702-2.Load flow studies in the presence of -5- geomagnetical ly-induced currents.IEEE Transactions on Power Apparatus and Systems.Vol.PAS-100,No.2.pp.603. Aspnes,J.D.,R.P.Merritt and S.-I.Akasofu.1981.Harmonic generationintransformersrelatedtoDCexcitationandsystemloading.IEEE Transactions on Power Apparatus and Systems.Vol.PAS-100,No.4. pp.1845-1851. Aspnes,J.D.,R.P.Merritt and S.-I.Akasofu.1981.Generator in the sky.Alaska Ruralite.pp.24-25. Aspnes,J.D.,R.P.Merritt and S.-I.Akasofu.1981.Effects of geomagnetically induced current on electrical power systems.TheNorthernEngineer.13(3):34-38. Wescott,E.,S.-I.Akasofu,H.Nielsen,and J.D.Aspnes.1981.Auroral induced currents in oil/gas pipelines and power transmission lines in Alaska.International Association of Geomagnetism and Aeronomy Bulletin No.45,Edinborough,Scotland.E.1.05. Aspnes,J.D.1980.Harmonic generation in transformers related to DC excitation and system loading.IEEE Power Engineering Society Meeting,Minneapolis.MN. Aspnes,J.0.,R.P.Merritt,and S.-I.Akasofu.1980.Auroral effects on electric power systems.Alaska Science Conference,Anchorage. Aspnes,J.D.,and T.C.Reihman.1980.Specifying regenerative heat exchanger arrays.Proceedings of the 4th Power Plant Dynamics, Control and Testing Symposium,Gatlinburg,TIN.pp.7-1 -7-9. Aspnes,J.D.1979.Solar heat gain through windows at high latitudes. Presented at Solar 79,Northwest Solar Energy Conference,Seattle, WA. Aspnes,J.D.,and J.P.Zarling.1979.Solar heat gain through windows at high latitudes.Proceedings of Solar 79 Northwest Solar Energy Conference,Seattle,WA.pp.208-211. Aspnes,J.D.,and J.P.Zarling.1979.Solar heat gain through windows at high latitudes.Alaska Science Conference,Fairbanks. Aspnes,J.D.1978.Dynamic control of a combined-cycle power plant: controller parameter optimization.Presented at 2nd International Symposium on Large Engineering Systems,Waterloo,Ontario. Aspnes,J.D.,and F.E.Gilman.Passive solar heating and cooling ofbuildings.1978.Northeast Regional Agricultural EngineeringService(an activity of the Cooperative Extension Services of the Northeast Land Grant Universities and the U.S.Department of Agriculture),NRAES,FS-9,Cornell University,Ithaca,NY. Aspnes,J.D.,and D.A.Pierre.1978.Magnetohydrodynamic/steam powerplantmodelingandcontrol.Energy Conversion,An InternationalJournal.18(2):101-113. Aspnes,J.D.,-D.A.Pierre,and T.C.Robles.1978.Reducing combustion air temperature variations in magnetohydrodynamic/steam power plants.Proceedings of 13th Intersociety Energy Conversion Engineering Conference,San Diego,CA.pp.1236-1241. Pierre,D.A.,and J.D.Aspnes.Dynamic control of a combined-cycle power plant:controller parameter optimization.Proceedings of 2nd International Symposium on Large Engineering Systems,Waterloo, Ontario.pp.457-462. Aspnes,J.D.1976.Magnetohydrodynamic/steam system dynamic modeling and control.Ph.D.Thesis.Montana State University,Bozeman,MT. 295 p. Aspnes,J.D.1975.Magnetohydrodynamic/steam combined-cycle modeling and computer simulation.Electronics Research Laboratory Report No.3675.Montana State University. va) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE ¢P.O.BOX 6300 *ANCHORAGE,ALASKA 99502-0300 «PHONE 907-563-7494TELEX:CHUGACH AHG (090)25 265 TELECOPIER: -564-RECEIVE?3Y _907-564-0632 ALAS¥*= "96 ABR 29 MO+16 April 24,1986 Alaska Power Authority P.O.Box 190869 Anchorage,AK 99519-0869 Attn:Mr.Ed Morris Subj:Intertie Budget:FY87 Dear Mr.Morris: As a result of the meeting on 4/24/86,I believe the following major tasks need to be done: 1.ML&P,GVEA,APA and MEA will provide a breakdown of their overhead costs in a manner similar to rate development. 2.APA will provide a list of tasks and associated hours for their labor costs allocated to the Intertie. 3.MEA will provide reasonable backup for the $108,581 Transmission Service charges. 4.The APA will develop standard accounting procedures for the capitalization of tools and equipment. 5.The APA will investigate insurance issues regarding both utility liability and transmission line insurance. Letter to Ed Morris April 24,1986 Page 2 6.Each Utility will investigate methods of financing reserves for repair. I thank you and each of the participants for their full and frank discussion of the budget. Very 'aly,aa.[lecA Mon spen eManagesofCost Control - and Adminystrative Services JES/be JS1:042486b cc:Virgil M.Gillespie,General Manager, Fairbanks Municipal Utilities System Michael P.Kelly,General Manager, Golden Valley Electric Assoc.,Inc. Thomas R.Stahr,General Manager, Anchorage Municipal Light &PowerB.Kent Wick,Interim General Manager, Alaska Electric Generation &Transmission Cooperative,Inc. KCS:Berk UNIVERSITYOF ALASKA-FAIRBANKS Fairbanks,Alaska 99701 May 7,1986 To:Reliability Subcommittee of the Alaska Intertie Operating Committee From:John Aspnes Sebi Ceprrse-Institute of Northern Engineering University of Alaska-Fairbanks Subject:Budget for the proposal to evaluate geomagnetic disturbances on the Alaska intertie This is in response to the Reliability Subcommittee request for separation of the above proposal budget into data collection and data analysis categories.If data analysis were not done,the student support at $13,000 and computer time at $1,000 would be deleted.Associated overhead savings of ($14,000)X (0.392)= $5,488 would also be in effect.Thus,cost of data analysis is approximately $19,488.Consequently,the data collection budgetwouldbe$55,387 -$19,488 =$35,899. It should be noted that a certain amount of analysis is necessary to verify validity of data being collected and to ensure that the system is calibrated and functioning properly. JA:DP:1892 INTERTIE ALASKA INTERTIE OPERATING COMMITTEE FY88 BUDGET SUBCOMMITTEE Dispatch/Training Dispatch/Scheduling Reliability/Criteria SCADA/Comm./Metering Machine Rating Reserves/Loadshed (1) (1) NOTES: FY88 OPERATING BUDGET PURPOSE Operating Procedures Manual Update System Analyses &Data Base Management Drafting Generation Standards Manual Update Review &Coordination of Loadshedding Secretarial Services Legal Services TOTAL (1)Cost associated with Operating Committee wettAMOUNT 5,000 100,000 3,000 3000 12,000 15,000 142,000 COLUmnm-wRitt@FY 87 MITCR -.”¥2ve oo .3/3 silss _8S/%e Aveease awore1 Seom TT oieooThTTcIannpoemanean|ean jo,>_CEA 226.12 O21 2b2)./9.20.4 lon 'oo.oan ot on oon pL etAEGTISN.2 155.12 st 9 |156.11 sh VdBoeeianne!pf}|7 MLeP 127-0 14S |SHY 266g 8 7 Z if tie -- 0 _Seuteen Tome ||ih HLu !Sod. 10 :i _oe."W Noe 7 iio |1G |Pry:|12 ao en a |: | ee - :.--+.eft 13 GVEA TTS |4 8 7 |g Mo noe 1!pope 15 FMUS ,28.2 .|29 115 g./3 cs Voie,6 - |i,it | _| | 1 NecTheen Total ||oeBene-r4 -an aan - ".-Sf po 4 20 CEA 210/509 =ttl 28.7 MW itu 21 ;_1.; : ({ _-2 AEQGT.156/509 =.31 eA Ay aris 7 er a nano aoeee» ANLP 143/Fe9 =29 |1S.Mw)|J as 25 Li ,.aa ||Loy |x GVEA Taal =14 su &.MW ee 7 7 |ol |Pf oe 2 =Oo FMUS 2B/ilaG =.26 |Pa MW oo. 290 -|pop |rtd ||_ u oo jHo.O MW : _. 1 |aft 'I fe _|ht ||1 |||| Bo iPod t to eens a Be GT BEE EEE SE oe. 35 je a J on mw I j 7 __ Hee ti iL a ott Lp ah nina _ ae es eee See ees ett 40 :tt oo. }1 |!|i GOLDEN VALLEY ELECTRIC ASSOCIATION ING.Sox 1249,Fairbanks,Alaska 99707 Phone 907-452-1151 May 6,1986 John S.Cooley,P.E. Chairman,Operating Committee 1200 E.First Avenue Anchorage,Alaska 99501 Dear John, The following peak loads are submitted for GVEA for the requested periods,yearly June 1 to May 3l. 83/84 84/85 85/86 74.7 MW 77.5 MW 81.4 MW Please let us know if you need any further information. LPfManagerofSystem Operations cc:Intertie Agreement File M.Kelly -GVEA R.Hansen -GVEA M.Riddle -GVEA E.Morris -APA YY ELECTRIC ASSOCIATION,INC. S601 MINNESOTA DRIVE ¢POUCH 6300 «ANCHORAGE.ALASKA 99502-0300 «PHONE 907-563-7494TELEX:CHUGACH AHG (090)25 265 May 9,1986 John S.Cooley Chairman,Intertie Operating Committee Anchorage Municipal Light &Power 1200 East First Avenue Anchorage,Alaska 99501-7671 Dear John: We agree on our interpretation of Section 7.2.1 of the Alaska Intertie Agreement.We also agree on the peak calculation for AEG&T,that is,the coincident peak for MEA/HEA.You should note,however,that MEA and HEA may not necessarily peak at the same time with each other or with Chugach Electric.My figuresforAEG&T are the maximum aggregate peaks for MEA and HEA in any one month.The Chugach peak includes the City of Seward. Period AEG&T CEA 06/01/83 -05/31/84 154,196 KW 226,204 KW 06/01/84 -05/31/85 155,201 KW 202,099 KW 06/01/85 -05/31/86 158,884 KW 202,916 KW If you have any questions or desire a different peak calculation, please do not hesitate to call me at 564-0603. Sincerely, an@-Marler ohn C.Marshall,P.E. Chief Design Engineer JCM/pkd4/M117 ec:Rick Newland Dora Gropp Tom Martin /NTERTIE |OPERA TIN ze 7 ComMITTEE MAL ZI,1986 HARRY BECK APA Ab/-7269 JIMA =AALL AGG ay 245--323) Katy, Mlershel!cB SOG-O6OR | Larry.Cole RAMUS YS6 S/CE8 w oo : Uprrvre i./e 6 ett fSfr-Ill/ Ed'flor:3 LOY?(4 PC/-Vargy Toten meP 363%-SY¥SD Arznn Ho Kua APA X61 -724¢5 Jousn Spence ceca SbEL--O7T+4- ra!too Ass T me ta S0AN STAFFORD APR LE/-7259 Alaska Power Authority State of Alaska May 20,1986 Mr.Edwin L.Morris,Secretary Alaska Intertie Operating Committee Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 Dear Ed: The Alaska Power Authority designates the following persons as representatives to the subcommittees of the Alaska Intertie Operat- ing Committee,as indicated: Budget -Harry Beck Reserves/Load Shed -Harry Beck replacing Howard Thacke The Power Authority also recommends that Dr.John Aspnes of the University of Alaska-Fairbanks be approved by the Operating Commit- tee for participation on the Reliability Subcommittee in an advisory role. Sincerely, Robert D.Heath Executive Director HLB:RDH:it cc:Dr.John Aspnes,P.E.,University of Alaska-Fairbanks 4408/340 PO.Box 190869 704 East Tudor Road Anchorage,Alaska 99519-0869 (907)561-7877 '\ Alaska Power Authority State of Alaska May 19,1986 Mr.Michael P.Kelly General Manager Golden Valley Electric Association,Inc. P.O.Box 1249 Fairbanks,Alaska 99707 Subject:Insurance Provisions of the Alaska Intertie Agreement Dear Mr.Kelly: Attached for your inclusion with your copies of the Intertie Agreement is a memorandum from Division of Risk Management reducing certain insurance requirements.This action was taken in response totheassertionthatamaximumof$6,000,000 was available to the coop-utility participants. The actions required under Article 17 have not been completed as yet.Copies of the insurance policies are required to be submitted to the Operating Committee and the Power Authority.Division of Risk Manager needs full copies to verify that the contractual requirements of Article 17 are covered in each utility's insurance policies.; The lowering of the limits for Section 17.2.2(a)and (b)will reduce insurance costs over the costs to provide the $10,000,000 coverage. This will help keep the Intertie rates down. Call Ed Morris or me if you have further questions. Sincerely, Robert D.Heath Executive Director RDH/EM:kyf Attachment as stated cc:Operating Committee G.Manni D.Hitchcock 4398/597 PO.Box 190869 §8=701 EastTudorRoad Anchorage Alaska 99519-0869 (907)561-7877 TO: THRU: FROM: 32-001 A(Rev 10.aa1 MEMORAK )UM Sta.e of Alaska Ed Morris DATE:May 12,1986AlaskaPowerAuthorityFILENO.: TELEPHONE NO.:465-2180 SUBJECT:==anchorage/FairbanksofRiskManagementIntertieInsurance tment of Administration RequirementsPECEIVED,BYSPRityThiswillconfirmourseveralconversations concerningadjustmentofmitimity}émens <3 liability insurance requiredfromcontractorsontheage/Fairbanks Intertie. Under Section 17.2.2(a)and (b)the minimum acceptable limitisreducedfrom$10,000,000.to $5,000,000.combined single limit per occurrence.t All other terms and conditions under the Intertie Agreementshallremainunchanged. XC?O.¢| Beetle Plann? -a ernae >o a ow md eee es Jes NO ia -%To Se Oatmoe-:to dag 00 r?<se 3 -7 ."2 mt me 33 -ae.=Pqs a Saye ot nos-wm et te oe Se taa e,se ¥ Municipality of Anchorage DEPARTMENT OF PROPERTY ANDO FACILITY MANAGEMENTRiskManagementDivision ANCHORAGE.ALASKA 99519-5050 (907)264-4201 TONY KNOWLES. VAYOR May 06,1986 RECE TLe 26 MAY 20 PI2:55 Ed Morris Alaska Power Authority P.O.Box 190869 Anchorage,Ak 99519 Res Alaska Intertie Insurance Requirements The Municipality of Anchorage,including all Municipal utility departments,is self-insured in the general liability and automobile liability areas effective January 1,1986 through January 1,1987. Excess liability insurance has not been purchased. If necessary,a copy of the audited annual financial report can be provided as an indication of the Municipality's financial strength. Sincerely ae Karen Reddy Insurance Administrator KIR/jrh ps t ?.ee Oe .i os »oeBReSeTSeepcanPenisCieANE Dann Sreya. a pais CERTIFICATE IS ISSUED AS A MATTER OF INFORMATION CNL ¢AND CONFZS5 ; IGHTS UPON TH ATE ER.THIS CERTIFICATE DOES NOT AMEND.' CORROON &BLACK,INC.EXTEND OR ALTER THE COVERAGE "AFFORDED BY THE POLICIES BELOW.4220 B STREET ANCHORAGE,AK 99503 COMPANIES AFFORDING COVERAGE Cowen'A SAFETY MUTUAL CAS CO r COMPANY BMEINSUREDLETTER M8 8 MUNICIPALITY OF ANCHORAGE Cotten'C in POUCH 6-650 COMPANYANCHORAGE,AK 99502 terten D COMPANY||LETTER E )COVERAGES ne sue macroes es Fa tical hdc odl eddie mua caeaddsaiadeaneaimaadadieticadeaicks o hndietaasdinatibondadaiaiies Aaeimomtson he :THIS IS TO CERTIFY THAT POLICIES OF INSURANCE LISTED BELOW HAVE BEEN ISSUED TO THE INSURED NAMED ABOVE FOR THE POLICY PERIOD INDICATED .NOTWITHSTANDING ANY REQUIREMENT,TERM OR CONDITION OF ANY CONTRACT OR OTHER DOCUMENT WITH RESPECT TO WHICH THIS CERTIFICATE MAY.pone ee.OR MAY PERTAIN,THE INSURANCE AFFORDED BY THE POLICIES DESCRIBED HEREIN iS SUBJECT TO ALL THE TERMS.EXCLUSIONS.ANO CONDI-ri ION F SUCH POLICIES. py eereerny LIABILITY LIMITS IN THOUSANDTYPEOFINSURANCEPOLICYNUMBERTedanteanaPOLCYExeigATON s occunénce |AGGREGATE GENERAL LABILITY BODILY COMPREHENSIVE FORM INJURY $$ PREMISES/OPERATIONS PROPERTY[|JNOERGROUND DAMAGE |¢$||EXPLOSION &COLLAPSE HAZARD PRODUCTS/COMPLETED OPERATIONS CONTRACTUAL domaneo |9 INDEPENDENT CONTRACTORS BROAD FORM PROPERTY DAMAGE PERSONAL iNJURY PERSONAL INJURY UTOMOBILE LIABILITY ANY AUTO ALL OWNED AUTOS \PRIV PASS ) ,QTHER THANALLOWNEDAUTOS(SEER IRS HIRED AUTOS PROPERTY NON-OWNED AUTOS DAMAGE {$ GARAGE LIABILITY BI &PO COMBINED $;-_1 :EXCESS LIABILITY -vag gi &PD '|UMBRELLA FORM Comaineo |$ |OTHER THAN UMBRELLA FORM STATUTORY | $100,EACH acc0ENT $500,DSEASE LCs AT $100,DISEASE face f4 Dyce %!WORKERS'COMPENSATION SP-1453-AK ANO 7 EMPLOYERS'LIABILITY OTHERi t DESCRIPTION OF OPERATIONS/LOCATIONS/VEHICLES/SPECIAL ITEMS ALASKA POWER AUTHORITY PO BOX 190869 ANCHORAGE,AK 99519 ATTEN:ED MORRIS SHOULD ANY OF THE ABOVE DESCRIBED POLICIES BE CANCELLED BEFORE THE EX- PIRATION DATE THEREOF,THE ISSUING COMPANY WILL ENDEAVOR TO MAIL 30 OAYS WRITTEN NOTICE TO THE CERTIFICATE HOLDER NAMED TO THE LEFT,BUT FAILURE TO MAIL SUCH NOTICE SHALL IMPOSE NO OBLIGATION OR LIABILITY OF ANY KINO UPOALTHE COMPANY.ITS AGENTS OR REPRESENTATIVES. AUTHORIZED BeEPRESENTATIVE Cz,b>/FaORIYA=i ACORD 25 (8/84)€UR/ACORD CORPORATION 1964 | /WTERTIE OPERATING MAY 21,19? HARRY =BECK APA JIMA HALL AEG EY Toby,WMlzrshel CIF Larry Cale RPS are Ld le Cet EL)lors esTotenmcr Arzar H.KHAW APA Jo us PENCE cea SAM AMR ide Ace T S04 STAFFORD COMMITTEE Ab/-7269 795-3271 564-0602 USC SICEwloo ffe-Ii] AC/-P2¥ 563 -SY¥SO 261-7245 SbQL-O774- 2E5-FIL 7 ees-7259 Ill. IV. VI. VII. VIII. IX. ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,JULY 16,1986 BEGIN at 1:00 P.M. Adoption of prior meeting minutes Approval/modification of agenda Committee correspondence and reports A.ODispatch/Scheduling Subcommittee B.Reliability SubcommitteeC. Intertie Status Update (A.P.A.) D.Special Subcommittee on Billings/Accounting Visitor comments related to items on agenda Old Business New Business A.Recess and work session B.Dispatcher/Scheduling C.Reliability D.Special Subcommittee on Billings/Accounting E.Insurance F .Others Formal Operating Committee action/recommendation Subcommittee assignments Adjournment Meeting location:Homer Electric Association 3977 Lake Street Homer,Alaska (907)235-8167 3928/591(1) Record CopyFile#iEPRO 274 ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,APRIL 23,1986(AT FAIRBANKS MUNICIPAL UTILITIES SYSTEM) Attendance: Sam Mathews Alaska Electric &Generation Cooperative Jim Hall Alaska Electric &Generation Cooperative Stan Sieczkowski Alaska Power Administration Harry Beck Alaska Power Authority Ed Morris Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power Mike Massin Anchorage Municipal Light and Power Ray L.Duncan Chugach Electric Association John C.Marshall Chugach Electric Association John Spence Chugach Electric Association Larry Colp Fairbanks Municipal Utilities System Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association John Aspnes University of Alaska -Fairbanks The meeting was called to order by Chairman John Cooley at 9:05 eat "the Main Board Room at Fairbanks Municipal Utilities SystemFMUS). Minutes of the preceeding meeting were distributed.Harry Beck stated that the minutes were late owing to the preparation of the revised budget package. Harry Beck stated that the minutes should be revised to eliminate "regularly"from page 7,paragraph 6.Bob Orr motioned that the minutes be corrected to include the Intertie Operating Committee budget as revised at the last meeting of the Operating Committee and that the corrected minutes be reviewed and adopted as corrected at the next meeting of the Operating Committee.Mike Massin seconded the motion.The motion was approved unanimously. John Cooley handed out "Actions of the Intertie Operating Committee"and indicated a correction needed to be inserted in the document before adoption by the Operating Committee.John Cooley further indicated that Dr.John Aspnes,P.E.of the University ofAlaska-Fairbanks (UAF)would be attending the meeting at 10:30 a.m. to discuss UAF's new study proposals. Bob Orr noted that he had sent a letter to UAF concerning their study,"Dynamic Stability Study of the Anchorage-FairbanksInterconnectedPowerSystem."A copy of this letter was furnished to the Operating Committee chairman.John Cooley then stated thatJohnAspnesofUAFhadsubmittedareplytoBobOrr's letter whichhadbeensenttoallmembersoftheOperatingCommittee.Bob Orr stated that he felt that no additional funds be provided for additional UAF studies until problems with the current study are 4265/596 1 resolved.John Marshall indicated that he had a problem with one of the cases concerning the relay actions.John Cooley moved that the agenda be amended to include discussion of the UAF study.John Marshall seconded the motion.The motion was approved unanimously. Marvin Riddle made a presentation on the meeting of the Dispatch/Scheduling Subcommittee conducted on April 22,1986 at 2:00 p.m.in the Training Room at GVEA.Minutes of the meeting were furnished and attached.Marvin Riddle reported that the March 4,1986 outage of the interconnected Anchorage-Fairbanks system was compounded by a lack of communications between the dispatch centers.He stated that a common communications link (i.e.voice) needs to be established to tie the dispatch centers together.He requested that all of the utilities review and comment upon the Operator's Manual provided earlier to the utilities. Harry Beck noted that the preliminary Intertie construction schedule for the summer would be out the following week and that it,along with a scope of work would be transmitted,when available,to the utilities and the Operating Committee for review and comment.Ed Morris noted that a revised version of the preliminary Alaska Intertie FY87 budget package had been prepared and distributed by the APA the previous week and that the APA would be presenting this package to the Operating Committee during work session.He further stated that he would like to receive enough information from the budget discussions to be able to establish an Intertie usage rate for FY86 assuming onset of commercial operation on May 1,1986.Ed Morris further requested comments concerning the Power Authority's intention to declare the Intertie commercially operational on May 1,1986.John Cooley reminded the members that input is required from the Intertie Participants for the FY88 budget by May 1,1986. Harry Beck stated that the Maintenance Agreements were out to GVEA &MEA for final review.Bob Orr stated that he had recently sent his comment letter to the Power Authority.Bob Orr questioned whether two separate agreements currently exist between the PowerAuthorityandCEA(for Teeland);a start-up construction agreement and a Maintenance Agreement.Ed Morris stated that he believes that there is only the start-up agreement and that there is no existing Maintenance Agreement. Bob Orr stated that GVEA can't meet the insurance provisions of the Alaska Intertie Agreement.He indicated that this was the subject of his comment letter concerning the Maintenance Agreement dated April 21,1986 noted earlier.He said that he had not seen any evidence that any other Participant including the Power Authority had purchased insurance coverage in the amounts required by the Alaska Intertie Agreement.Ed Morris concurred.Bob Orr furthernotedthatnoonecanobtainthislevelofcoveragethisyear.Ed Morris indicated that he would refer this matter to the State's Division of Risk Management for review and,hopefully,mitigation of the insurance provisions. 4265/596 2 John Cooley requested that all of the Participants review their present insurance coverage. Mike Massin then reported that he intended to have the Intertie Manuals ready for the next meeting and that all members would be encouraged to review them. John Cooley reported that the Operating committee had received a letter from John Aspnes concerning the UAF dynamic stability study. John Cooley also distributed two new UAF proposals,"System Analyses and Data Base Management"and "Evaluation Of Geomagnetic Disturbances On The Anchorage-Fairbanks Transmission Intertie" (previously distributed at last Operating Committee meeting).See attached. Bob Orr said that in his opinion,there were no results from the UAF study.He indicated that he had written a letter to John Aspnes critiquing the study.Bob Orr stated that the GVEA review comments contained in the letter were authored by Henri Dale.Bob Orr then read this letter to the Operating Committee.He indicated that he objected to the conclusions reached in the study concerning load shedding.Bob Orr then read the reply from John Aspnes.Mike Massin then stated that he felt the utilities should have a.better handle on the data base and the study as a whole. Ed Morris moved that the problems with the UAF study identified by Bob Orr be referred to the Reliability Subcommittee for resolution. Sam Mathews seconded the motion.Bob Orr said that he felt that this issue had been beaten to death already.Mike Massin stated the Reliability Subcommittee would be a good avenue for resolving this issue.Sam Mathews said that there should be some way to rescue the study and the data base considering the amount of time and effort already expended in their preparation. Bob Orr said that the study lacked someone with utility experience associated with it.Jim Hall indicated that individual utility experience may not have been enough experience to overcome all of the problems reported.Bob Orr countered that anyone with utility experience could have provided this oversight needed by the project.John Marshall stated that a key problem was that the Operating Committee never developed a specification for the work.John Spence added that the original proposal doesn't outline the obligations Of all of the parties.He added that UAF couldn't possibly know or identify all of the odd problems encountered in utility operation.He concluded that a single source at the Operating Committee is needed to provide the leverage with the utilities if the data and information from them isn't being provided. The motion on the floor was brought to a vote and defeated. John Cooley then motioned that a specification for the UAF proposal "System Analyses and Data Base Management"be developed by the 4265/596 3 Reliability Subcommittee.Bob Orr seconded the motion.The motion was adopted unanimously. Discussion then turned to the UAF proposal "Evaluation OfGeomagneticDisturbancesOntheAnchorage-Fairbanks TransmissionIntertie."Bob Orr stated that the utilities and the Power Authority had already contributed to this project at no cost to UAF.Mike Massin said that in view of the alternate energy sources that may soon be evaluated for the Railbelt this issue should be reviewed.Sam Mathews stated that we shouldn't ignore it.John Marshall said that providing facilities and technical assistance is fine but that some of the utilities may have a problem with the Operating Committee funding it.Mike Massin stated that his utility would have to justify the study with the benefits to be achieved for his rate payers. John Aspnes from UAF arrived at this point.He then provided an overview of previous work performed in this area by UAF and others. He stated that the results of the study would show whethergeomagneticallyinducedcurrents(GIC)would adversely affect Intertie operation.Bob Orr asked if the UAF work already performed had indicated any problems would be likely to occur. John Aspnes replied "no"based on the simplified circuit initially in-place and the limited amount of work already performed.John Aspnes then described problems with GIC in the Manitoba system. Discussion then focused on potential problems with relay misoperation due to GIC and the communications channels to be used for data acquisition. Discussion then turned to the paths for dc currents through the Intertie transformer neutrals and the instrumentation installed at the substations for monitoring them.Ed Morris then suggested that this proposal be referred to the Reliability Subcommittee for disposition similar to that for the other proposal.John Marshall agreed.John Aspnes stated that there is a time crunch on this work.He indicated that he would like to be able to fund his students for the summer.Stan Sieczkowski asked if UAF could gather the data now and hold off on the analysis to contain costs. John Spence asked if the utilities could obtain this data for UAF. John Aspnes said "no"owing to the complexity of the equipment and the need for accuracy in measurement. Bob Orr thén moved that this proposal be referred to the Reliability Subcommittee with the same direction as that provided for the previous proposal.Sam Mathews seconded the motion.The motion passed unanimously. There were no visitors present at the meeting. The was no Old Business to consider. It was proposed that the Operating committee adjourn for an early lunch in order for John Aspnes to attend lunch with members of the 4265/596 4 Operating Committee.The Operating committee recessed for lunch at11:30 a.m. The Operating Committee reconvened at 1:15 p.m.in the crew room at the plant of Fairbanks Municipal Utilities System. Under New Business,the Operating Committee went into work session at 1:15 p.m. Under budget,Ed Morris presented the April 14,1986 updated version of the initial budget for the Intertie.The budget of $1,763,755 was 39%less than the previously proposed budget.The Operating Committee agreed by concensus to increase the OperatingCommitteefundingforstudiesfrom$98,900 to $100,000 and to add secretarial services of $12,000.This brought the new Operating Committee budget to $142,000.Members of the Operating Committee noted that the decision to spend any or all of the $100,000 for studies has not yet been made but was included for budgeting purposes. John Spence questioned the reasonableness of the 260 GWh usage figure.Harry Beck explained that it was the sum of the FMUS and GVEA purchases estimates provided in the budget document.John Spence noted that if the purchases failed to materialize,the shortfall will be subsidized by the southern area utilities. Bob Orr explained that the maintenance will be paid monthly but will be adjusted at year end to actual costs.If extraordinary maintenance is required,it becomes an above the budget expense that is paid.Mike Massin stated that excess payments in a yea will be paid back to the utilities. Sam Mathews asked what reports would track expenditures.Ed Morris suggested that the Budget Subcommittee determine what information should be reported.Harry Beck stated that the APA will provide the accounting and can produce information for the Subcommittee. Sam stated that this first year will be the worst for making budget projections for energy sales.Bob Orr felt that this coming year's sales would be lower as charges for the Intertie would be in effect and competing energy sources costs would be lower. Discussion on SCADA depreciation resulted in the decision to use a 10 year period with no interest with 1/10 depreciated each(straight line formula)year. John Spence felt that overheads for labor rates over 40%were excessive.The 40%would cover labor benefits and not general andadministrative(G&A)items such as vehicles.He felt that the G&A costs were not increased due to Intertie Operation and should not be included.GVEA,ML&P and APA agreed to provide accounting breakout of overhead information for further discussion. 4265/596 5 Further discussion prompted the plea for APA to produce one budgetbookwithallmaterialsincludedforeasyreference.Also requested was a distribution of copies of the Maintenance and Transmission Service Agreements for review by Committee members. A question was raised if $39,915 for GVEA substation costs was duplicated in the Northern Operators Agreement and the Maintenance Agreement.8ob Orr was unable to answer without first conducting a review. Mike Massin was concerned about the outright purchase of maintenance equipment for the Intertie and if it was only for Intertie use.Bob Orr responded that this was for specialty equipment required to do maintenance and would only be used for that purpose.There would not be a recurring charge in the next year's budget. Bob Orr requested that the APA provide more detail on the engineering duties.Ed Morris responded that this was a composite of operating engineer work and must be recovered from 0&M budget revenues.It does not include any of Morris'time as that is an administrative cost not recovered in O&M charges.Harry Beck agreed to provide detailed information on expected engineering activities.. John Spence objected to the exclusion of maintenance costs for their data link.Mike Massin stated that only their capital costs for SCADA are reimburseable and that the data link benefits Chugach as it is a full two-way system.Chairman Cooley directed the APA to review the agreement with Chugach and report. John Spence questioned the derivation of the MEA transmission charges.Bob Orr stated that he expected the APA to ensure that they are fully correct and expected the APA to have the accounting records.Ed Morris said that an audit of their accounts would verify the information but it was not on hand now.Mike Massin reminded the group that the operating agreement provision requires wheeling charges based on the negotiated agreement between MEA and APA.Bob Orr pointed out that the formula specifies that the energy sales figure should be used for the rate calculation. Marvin Riddle stated that the DIVCOM cost was too high.Bob Orr cited GVEA experience and rates that suggested that DIVCOM is charging for more than his estimate of $28,000 to maintain.John Cooley opinioned that the state may not be as efficient as Motorola Services and that we are paying too big a share of their budget. APA will again request detail of DIVCOM's expenses for the facilities. Ed Morris proposed that an annual minimum of $100,000 be set asideforR&R.As long as the Power Development Loan Fund (PDLF)was solvent,emergency loans could be used to meet R&R expenses beyond the reserve on hand.The repayment period of 10 years would 4265/596 6 approximate a capital depreciation period but not be as valid as using a true reserve fund.John Spence asked how the utilities might provide a sinking fund.Mike Massin felt that it could be done much as utilities provide reserves for deductible portions of insurance.Bob Orr felt that the transmission line insurance question has to be answered first or the R&R requirements would be wide open.Mike Massin suggested that the Committee look further into R&R reserve options. Under formal Operating Committee action,Chairman Mike Massin directed the RELIABILITY SUBCOMMITTEE TO MEET ON WEDNESDAY,APRIL 30,1986 AT 9:00 A.M.AT CHUGACH ELECTRIC ASSOCIATION for the purposes of reviewing the study proposals from UAF and to develop specifications for them. John Cooley moved that $142,000 be approved for the Intertie Operating Committee budget for FY1987.Bob Orr seconded the motion.The motion was adopted unanimously. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,MAY 21,1986 AT 9:00 A.M. IN THE EXECUTIVE CONFERENCE ROOM AT THE ALASKA POWER AUTHORITY AT 701 £.TUDOR ROAD,ANCHORAGE,ALASKA. Larry Colp then motioned for the meeting to adjourn.John Marshall seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 3:20 p.m. Respectfully submitted,© fanny L.Rect_ Edwin L.Morris,Secretary Alaska Intertie Operating Committee 4265/596 7 Attachments: 1.May meeting agenda 2.Minutes from April 22,1986 Dispatch Scheduling Subcommittee Meeting 3.Corrections to Minutes for March 19,1986 as noted at April 23,1986 Intertie Operating Committee Meeting 4.Golden Valley Electric Association letter to University of Alaska-Fairbanks dated April 4,1986 5.University of Alaska-Fairbanks letter to Golden Valley Electric Association dated April 16,1986 6.Actions of the Alaska Intertie Operating Committee 7.Alaska Intertie Operating Committee FY87 Operating Budget(corrected) 8.Draft Proposal to Intertie Operating Committee,"System Analysis and Data Base Management" 9.Draft Proposal to Intertie Operating Committee,"Evaluation of Geomagnetic Disturbances On the Anchorage-Fairbanks Transmission Intertie" 10.Attendance list from April 23,1986 Intertie Operating Committee meeting 4265/596 8 L PATCH SCHEDULING COMMITTEc .EETING April 22,1986 at 2:00 p.m. GVEA Training Room In Attendance: Ray Duncan -CEA Stan Sieczkowski -Ak Power Admin Marvin Riddle -GVEA Alan Martin -FMUS Discussion on March 4,1986 outage -biggest problem appears to be a communication problem between all the Dispatch Centers.This lack of communication appears to add confusion to restoration process, especially during black start.This could be greatly improved by having a common telephone link. Comments on Intertie Restoration: 1)Do not close 538 at Teeland if Douglas Bl is closed and re-energizing from the South. 2)GVEA should not re-energize Intertie from North until Douglas Bl is open,splitting the line to be picked up. 3)Test Teeland-Douglas line one time after relay action,after all parties are notified,the same rule applies to Healy and Douglas line. 4)Need to be certain Intertie schedules are zeroed before re-energizing. Went over Intertie bubble memory meter readings for March.Supplied copy to CEA-AML&P. CA®0 Asura Discussed planned outage scheduled for April 24-25.CEA provided outline of work and switching order (see attached). One copy of the Operator's Manual was provided by Marvin for comments from FMUS,GVEA,AML&P,CEA,AEG&T.Responses needed as soon as possible so final book can be assembled for Dispatchers. CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska April 17,1986 TO:See Distribution FROM:Ray L.Duncan,Manager of Power Control Ket. SUBJECT:Conversion of Teeland Substation to 230 KV Attached vou will find a sketch of Teeland Substation and the proposed switching that will be required to deenergize the existing 138/115 KV transformer,energize from Pt.MacKenzie to Teeland at 230 KV,move the 34.5 KV feed to Site Bay from its existing source to the tertiary of the 230/115 KV transformer and swing the Anderson and Herning 115 KV lines into their separate permanent bays. I have numbered the switching steps so we can make sure everyone involved is talking about the exact same step.Generally,the steps will be carried out sequentially,but some sections will be skipped over in order to do various jobs at the same time. Example:When Step #6 has been completed and we are in the process of completing the isolation of the existing 138 KV system,we can go to Step ¥8 and start the switching necessary to deenergize the 138/115 KV transformer,as we need to remove its bushings,and the 138 KV between disc #4729,#4715 and #4717 must be dead to do this.The problem with sequencing the steps in order to go l -2 -3 etc.,is the time frame between each step.The present schedule is for the outage to be April 24 and 25.I am attempting to get an additional day (April 23)added to the outage time,but as of now,it is scheduled for just the 24th and 25th. Please distribute copies to everyone in your area that will be involved or may be able to make a contribution.This switching is laid out as I feel will work,and if you have any suggestions or questions,please call me at X 789.A meeting concerning this will be held 0930 Mon.,April 21,in the Engineering Conference Room. RLD/bec MISC1:041786a Attachment ce:GLD:File 000 Memos J.Marshall D.Hall,ML&P db/Read File M.Tullius J.Hall,MEA A.Berg V.Watson M.Riddle,GVEA D.Burlingame T.Wellman G.Davis °o-:. .%'' . -|&3 a fe], t had :8 "S !iN!x zy &\. +©a |° "u ... ;X S so2s\Has 135 ay -¥ae :=G . ,;MLL,__s01S q VMS 'yale \i :TT/00 ©; : ' an -_Vovg he /o/o se Lael 13/0 ' O/T 4 MIN.7409\iN s30F .SN 138 253 '[&pr Zo -{ i eee Sf ' i >ar )z i uv gi7 mo ok 515 \' -|o ay SKY ;538 S17BATK ply |UL |; .ANSiteBay;37 370 25 Mm , ;,,;:230kKV :ro b $25 jus! WIS YAS j L a \ A ar v :-- 4410 |MN ste . )SVS "EN _WY Gaye bo W De 182 DN EK: :13/0 1325aa)T 4YSA,510 i 55 ;WUT \._. 15 IS Lo L \\(8)7?"|nN 230 KV Wold Bo ve.-!yees |>we 4795-Sols K ; : ';47/10mo.Ty °Yolo |4729 oo ' 'SWITCHING ORDER ATE: CLEARANCE NO, NO.|STATION |SWITCH NO.||TIME 1 |Eklutna |Brk #362 |Request ML&P to have breaker closed | _|||| 2 |Teeland |Brk #4510 |Ck.Open | |||t 3 ||Brk #4410 |Ck.Open | |||| 4 ||Disc #4315 |Ck.Open | ||| 5 ||Disc #4525 |Ck.Open | |||| 6 ||Brk #4610 |OPEN | L ||| 7 |Pt.Mck.|Brk #838 |OPEN ||| 8 ||Disc #917 |OPEN Red Tag_CLé#| |[i | 9 ||Disc #925 |Ck.Open Red Taq CL#| |[|] 10 ||Brk #4420 |OPEN | ||-|| 11 ||Brk #4410 |OPEN | |L || 12 ||Disc #4417 |OPEN Red Tag CLE | I ||| 13 ||Disc #4412 |OPEN Red Tag CL#| I || FORMS :41686b -1- ' CLEARANCE NO, SWITCHING ORDER DATE: NO.|STATION|SWITCH NO.||TIME 14 |Teeland |Disc #4315 |Ck.Open Red Tag CL#| ||| 15 ||Disc #4615 |OPEN Red Tag CL#| |||This will permit operation and checking | L.||MO Disc #4619 | |||| |||We should be in a position to issue a | |||clearance for them to swing the conductors | |||fram the 138KV buss to the 230KV buss { |at Pt.Mck.l ||| l6 |Teeland |Disc #4729 |OPEN SC Hold Open CEA Disp.| |||| When we are ready to energize 230KV @ Teeland | |||| 17 |Teelard ||Ck.following breakers Open | 18 |_||_#4610 | 19 ||[#4410 | 20 |||#1010 | 21 |[_|#1110 | 22 |||#1210 || |||Note breaker #1310 is being used as | |||breaker #434 | i ||| |i |Ck.following disconnects Open | 23 |L |L FORMS :41686b -2- DATE: CLEARANCE NO. SWITCHING ORDER --- NO.|STATION [SWITCH NO.||TIME | 24 |||#1025 || 25 |||#1015 || 26 |||#1125 || 27 |||#1115 || 28 |l |#1225 || 29 ||#1215 || 30 ||#1019 || 31 ||[#1119 || 32 |||#1219 || I |||| |Teeland ||The following disconnects should be ck.closed |.| ||||| 33 |||#4415 || 34 |||.#4425 || 35 |||#4625 || 36 |||#4515 || |||| 37 |[Brk #310 |Ck.Open | |||__| 38 |[Disc #319 .|Ck.Open SC Tag | |i [ 39 |[Disc #317 _|Ck.Open SC Tag | |||| 40 |Teeland |Disc #4619 |Check Closed | |||| |||| FORMS:41686b -3- CLEARANCE NO, .SWITCHING ORDER DATE: NO.STATION |SWITCH NO.|T Tre. 41 |Pt.Mck |Disc #4417 |Remove Red Tag CLOSE -| L ||__a __|= 42 ||Disc #4412 |Remove ;.Red Tag CLOSE | |||| 43 ||Disc #4429 |CLOSE {. 43a|Teeland |Brk #434 |OPEN | 43b|ML&P |Brk #4710 |Have ML&P OPEN | 44 |Teeland |Disc #4615 |Remove Red Tag CLOSE | 45 |Teeland |Disc #4315 |Remove .Red Tag CLOSE | |! 46 |Pt.Mck|Brk #4429 |CLOSE | |||This will heat up 3 pt's and to Brk's #4410 | |||and 4610 @ Teeland | |||| || | 47 |Teeland |Brk #4410 |CLOSE | |I |This should heat up 230/115 KV Bank @ Teeland | |||and the tertiary @ 34.5 KV | J ||__| 48 ||Disc #319 |Remove SC Tag CLOSE | 48a||Disc #?|Line side of Disc #319 CLOSE | 49 ||Disc #315 |Ck.Closed | 49a||Disc #317 |Remove SC Tag Only | 30 ||Brk #310 |Phase across breaker if in 6 | |[|L 51 ||Temp 34.5 KV|Breaker feeding Site Bay OPEN FORMS :41686b a4- CLEARANCE NO. Se SWITCHING ORDER DATE: NO.|STATION |SWITCH NO.|[TIME |||| 52 ||Brk #310 |CLOSE { 52a|Fuses 115 KV side of 115/34.5 KV Transformer OPEN | 53 |f |This will permit removing the temporary | |on |115/34.5 KV transformer and removing the | |||conductor to the Site Bay line | L ||| 54 ||Disc #1215 |CLOSE | |||| 55 ||Disc #1219 |CLOSE | |I || 36 ||Disc #1115 |CLOSE | |-I | 57 ||Disc #1119 |CLOSE | ||| 58 ||Brk__#1210|CLOSE | |a || 59 ||Brk #1110 |CLOSE | |=| 60 ||-|This will permit phasing the Herning circuit |_ |||at the pole | |||| 61 ||Brk #1110 |OPEN | |||| 62 ||Disc #1125 |Ck.Open CL #| FORMS :41686b -5- ATE: SWITCHING ORDER CLEARANCE NO. --_-__-_-- NO.|STATION |SWITCH NO.|[Tie 63 ||Disc #1115|Ck Open Red Tag CL#[ |||| 64 ||Disc #1015 |CLOSE | |||| 65 |.|Disc #1019 |CLOSE | |||| 66 ||Disc #1015 |CLOSE | |||_| 67 ||Brk #1010 |CLOSE ||| |I |This will permit phasing the Anderson circuit | |||at the pole | ||| 68 ||Brk #1010 -|OPEN | |||| 69 ||Disc #1015 |OPEN Red Tag CL | ||| 70 ||Disc #1025|Ck Open Red Tag | ||| ||-|This will permit making up the Anderson&[ |||Herning circuits at the poles | L ||| 72 |||When the circuits have been closed at the | i"||poles we will phase between the 115 KV Pt's | |[|and the 230 KV Pt's | | FORMS:41686b CLEARANCE 2:0. SWITCHING ORDER DATE: NO.|STATION |SWITCH NO.||TIME il 73 =||Disc #1015 |Remove Red Tag CLOSE || ||||| 74 ||Disc #1019 |CLOSE || ||||| 75 _||Disc #1025|Remove Red_Tag Only L | |||| 76_||Brk #1010 |CLOSE || ||| 77 '|||This will permit phasing between 115 KV || |||and 230 KV Pt's (Anderson)|| ||||| 78 ||Brk #1010 |OPEN | ||__||| 79 ||Disc #1119 |CLOSE || ||| 80 ||Disc #1115 |Remove Red Tag CLOSE | |||| 81 ||Disc #1125 |Remove Red Tag Only | ||| g2 ||Brk #1110,|CLOSE l ||i | 83 |||This will permit phasing between 115 KV | |||Pt's and 230 KV Pt's (Herning)| ||| FORMS :41686b -T- NO,CLEARANCE SWITCHING ORDER ATE: |This will permit separating the 2 115 KV |circuits in the field 85|MEA NO.|STATION |SWITCH NO.| FORMS :41686b CLEARANCE NO. -- SWITCHING ORDER DATE: NO.|STATION |SWITCH NO.||TIME 101 |Teeland |Disc #4715 |OPEN Red Tag CL#| _|||| 102 ||Disc #4717 |Ck Open Red Tag CK#| !|| _ | 103 ||Brk #538 |Oven Pepe mpee |mi _|This will separate from Douglas &Intertie | Lt || 104 ||Disc #515 |Open Red Tag CL#¥| I I || 105 ||Disc #517 |Ck.Oven Red Taq CL#| |||This should permit the removing of the | |||jumpers around the APA 230/138 KV bank | |||and making up the leads to the 230 KV | |||side of the transformer | |l ||| 106 |When Jumpers have been removed frem APA's 230/138 KV,transformer | |||and 230 KV side closed in.|| ||| 107 ||Disc #4729 |Remove Red Tag &CLOSE | ||-_|| 108 ||Disc #4715 |Remove Red Tag &CLOSE | |||L 109 ||Disc #4717 |Remove Red Tag ONLY | |||| 110 ||Brk #4710 |CLOSE | |L |I FORMS :41686b -9- DATE: SWITCHING ORDER NO.|STATION |SWITCH NO.| 111|ML&P |Put SVS back in service 112 |Teeland |Disc #515 |Remove Red Tag CLOSE ia ||| 113 ||Disc #517 |Remove Red Tag ONLY | |L i | 114 ||Brk _#538 |Synchronize and CLOSE | lL || 115 |ML&P ||After load check have ML&P open Eklutna | |||Brk #362 l to [|| _|![| i || |||| || |=| |=|| i ||| ||| ||| t || |||| ||=L |i L | i ||| il L || FORMS:41686b 10- Alaska Intertie Operating Committee Wednesday,March 19,1986 (At Anchorage Municipal Light &Power) Attendance: Sam Mathews Alaska Electric &Generation Cooperative Jim Hall Alaska Electric &Generation Cooperative Harry Beck Alaska Power Authority Dave Eberle Alaska Power Authority Afzal Khan Alaska Power Authority Ed Morris Alaska Power Authority Howard Thacke Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power Larry Hembree Anchorage Municipal Light and Power Mike Massin Anchorage Municipal Light and Power Ray L.Duncan Chugach Electric Association John C.Marshall Chugach Electric Association Larry Colp Fairbanks Municipal Utilities System Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association John Aspnes University of Alaska -Fairbanks The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Engineering Department Conference Room atAnchorageMunicipalLightandPower(ML&P). Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unani- mously. Mike Massin suggested that the agenda be amended to reflectDaveEberle's presentation at 11:00 a.m.and to include (1)Univer-sity of Alaska -Fairbanks (UAF)Dynamic Stability Study presenta-tion,(2)discussion of interconnected system collapse of March 4, 1986 and,(3)FY86 Intertie Operating Budget.Mike Massin motioned for the agenda to be adopted as amended and John Marshall seconded the motion.The motion was approved unanimously. Marvin Riddle made a presentation on the joint meeting of the Dispatch/Scheduling and Dispatch/Training Subcommittees conducted on February 12,1986 at 9:00 a.m.in the Executive Conference Room at ML&P.Minutes of the meeting were furnished and attached.He reported that the subcommittee had discussed the upcoming seminars to be provided by the UAF Electrical Engineering Department for system dispatchers.He stated that UAF would be conducting two advanced seminars only,one scheduled for the week of June 2,1986 and the other the week of June 9,1986.Finally,he commented that these sessions will be conducted by Professors Robert Merritt and George Mulligan.The course outline for the seminars is included with the minutes. 3928/591(2) Marvin Riddle stated that the scheduled outage (Feb.19-20,1986) of the Teeland -Pt.Mackenzie line required to swing towers did not occur.Ray Duncan and Marvin Riddle then discussed the next available date for a scheduled outage at Teeland required in order to complete the 230 kV conversion work.Ray Duncan stated that the earliest date available appeared to be the 3rd week of April. Ed Morris then stated that he would notify the Participants of the expected date of arrival of General Electric (GE)engineer Don Homer.He said he would confirm whether a tieline outage isrequiredwhiletheStaticVarSystem(SVS)at Teeland is out-of- service.Bob Orr then stated that the expected downtime for the SVS while modifications are being made to it will be two to three days. Marvin Riddle then submitted copies of the NERC Operating Guide #9 and recommended that it be adopted by the Operating Committee. Mike Massin stated that the preparation of the Intertie Manual would soon be completed.Bob Orr stated that the system operators need these operating guides in a manual form. Turning to Intertie Status Update,Harry Beck reported on the status of the preparation and completion of the Maintenance and Transmission Service Agreements for the Alaska Intertie.He noted that the Maintenance agreements were being sent to Golden ValleyElectricAssociation(GVEA)3nd Matanuska Electric Association for final review and comment.He further noted that the Transmission Service Agreement was still being reviewed by the Alaska PowerAuthority(APA)and the Attorney General's office.Afzal Khan reported that the SCADA Agreement with ML&P was ready for signature by both parties.Harry Beck stated that review copies of the SCADA,Maintenance and Transmission Service agreements would be made available to all Operating Committee members pending comple- tion of the signature process. Harry Beck noted that the preliminary Alaska Intertie FY87 budget package had been prepared and distributed by the APA the previous week and that the APA would be presenting this package to the Operating Committee during work session.He further stated that Jim Hall would report on the March 4,1986 fire in the breaker at the Douglas Substation when the system outage is discussed under work session. Mike Massin then reported that Afzal Khan,Harry Beck and himself had preliminarily reviewed the material comprising the Intertie Manual.He indicated that this manual would include signed copies of all agreements relating to the Intertie.He further stated that procedures and operating guidelines adopted by the OperatingCommitteewouldberetypedandinstalledinthemanual. 3928/591(3) testing.Dave Eberle said that GE was proposing to conduct a sim-plified loss test in which the SVS devices would be checked throughtheirallowablerangeofoperation.He said that the Power Author- ity was examining this alternative testing procedure.Finally,Dave Eberle stated that the problem identified as #14 (i.e.,SVS stabilizing transformer critical power)in Bob Orr's letter to the Alaska Power Authority dated November 12,1985 was apparently not clear to Power Authority staff.Dave Eberle requested clarifica- tion on this item.Harry Beck stated that he had not seen any documentation concerning this problem and that it was therefore difficult to proceed with a solution in concert with Commonwealth Associates.Bob Orr indicated that he felt the problem was already adequately documented.Mike Massin asked how this problem is eliminated at SVS installations elsewhere.Discussion continued on these questions/statements.Finally,Dave Eberle indicated that this problem and possible solutions would be explored by the Power Authority. The Operating Committee then recessed for lunch at 12:00 p.m. The Operating Committee reconvened at 1:15 p.m. John Marshall provided a brief description of the system outage of March 4,1986 from the perspective of the CEA system.Mike Massin then provided a brief description of the system outage from the perspective of the ML&P system.Bob Orr discussed the GVEA system response during this outage.Finally,Jim Hall discussed the fire in the Douglas breaker which occurred that same afternoon. Under Operating Committee Manuals consolidation,Mike Massin reported that the new manual will be put together soon and handed out to each of the designated representatives of the Operating Committee. Under Election of Officers,Bob Orr nominated John Cooley for Chairman.Afzal Khan seconded the nomination.The motion to elect was passed unanimously.Finally,Bob Orr nominated Ed Morris for Secretary.The motion to elect was passed unanimously. Under budget,Ed Morris presented addenda to the "Alaska Intertie Budget"dated March 12,1986.These addenda included a chronology and status of current budgetary obligations of the Participants. Ed Morris stated that the Intertie is still operating under the testing agreement and that a budget needs to be established prior to commencement of commercial operation.He then requested that all Participants review the proposed budget package. Jim Hall stated that the figure for MEA Transmission Service wastoohigh(i.e.,$250,000)and that he felt this figure would beshowntobeontheorderof$75,000.John Marshall said that CEA had established a budget review committee and it would be meeting 3928/591(5) on March 25,1986 to discuss the budget package submitted by the Power Authority.He added that CEA had no official comments to make at this time. Bob Orr then questioned the Teeland Substation Maintenance figureof$28,000 stating that it was high in relation to expected costs at Healy and Goldhill.Harry Beck stated that this was an old figure and was used in lieu of any new information from CEA. Bob Orr stated that the maintenance contract between CEA and the Power Authority was a start-up contract and he questioned using a cost associated with this contract for the purpose of estimating maintenance costs.Ed Morris indicated that the Power Authority would review both the existing maintenance contract with CEA and the expected costs of maintenance at Teeland. Bob Orr stated that the amount for communications operations andmaintenancewastoohigh(i.e.,$65,000).Afzal Khan explained that this figure was provided by Mike Ridge of the State DivisionofTelecommunications(DIVCOM).Bob Orr indicated that he felt an adequate amount for this service based on GVEA's experience with their own equipment was on the order of $10,000 per year.He requested that DIVCOM be requested to furnish scope and documenta- tion for these costs. Discussion then turned to insurance coverage for the line and substations.Harry Beck indicated that the Power Authority does not have insurance coverage for the transmission line itself.He indicated that only the Intertie substations and their equipment are covered by insurance.Mike Massin asked about equipment and property insurance for the 4 Dam Pool projects.Ed Morris ex- plained the provisions of insurance for the 4 Dam Pool.Bob Orr both felt that the R&R portion of the budget should be dropped and only provided for at the end of the fiscal year should the need to use R&R funds arise.Ed Morris then countered with the question as to where the funding would come from for doing this.Bob Orr stressed his concern about the lack of insurance for the trans- mission line.Ed Morris stated that the Power Authority would address this question of insurance coverage and R&R funding during the budget review period of the next few weeks. Discussion then turned to the Alaska Power Authority portion of the budget.Ed Morris explained the breakdown of this budget item. Bob Orr stated that the total amount was too high.Ed Morris indicated that a lot of these costs are allocated costs associated with operation of the Power Authority itself and that they must be recovered:that there is no provision for capturing these costs from any other source of funding other than Intertie Operations and Maintenance.Ed Morris stated that the Power Authority's costs would be reviewed in the hope of lowering these allocated amounts. 3928/591(6) Turning to the budget of the Intertie Operating Committee,costs associated with some of the subcommittees were revised.The total proposed Operating Committee Budget for FY87 is $142,000.See attached.It was the consensus of members of the Committee that studies should be funded through the committee and not through the Power Authority where allowable.The Operating Committee's authority to directly contract for services was questioned.It was decided that this question be reviewed by the Power Authority and it's legal counsel. Finally,Harry Beck asked all Participants to forward to the Power Authority their written comments on the budget package and their revised budget estimates no later than April 1,1986. Turning to Subcommittee assignments,CHairman Mike Massin directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET ON TUESDAY,APRIL 22, 1986 at 9:00 A.M.IN THE TRAINING ROOM AT GOLDEN VALLEY ELECTRIC ASSOCIATION for the purposes of reviewing the Operating Procedures Handbook and the Operating Guidelines. Under formal Operating Committee action/recommendation,Bob Orr motioned that the Operating Committee adopt the NERC Operating Guide #9,"Action In An Operating Capacity Emergency".Mike Massin seconded the motion.The motion was adopted unanimously. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,APRIL 23,1986 AT 9:00 A.M.IN THE MAIN BOARD ROOM AT FAIRBANKS MUNICIPAL UTILITIES SYSTEM AT 645 FIFTH AVENUE,FAIRBANKS,ALASKA. Larry Colp then motioned for the meeting to adjourn.John Marshallsecondedthemotion.The Operating Committee then unanimously adopted the motion to adjourn at 4:35 p.m. Respectfully submitted, Edwin Ui Morris,SecretaryAlaskaIntertieOperating Committee 3928/591(7) Attachments: 1 2 3. 4 on12. 13. April meeting agenda Minutes from February 12,1986 Dispatch Scheduling -Dispatch Training Subcommittee Meeting NERC Operating Guide #9,"Action In An Operating Capacity Emergency" Golden Valley Electric Association letter to Alaska Intertie Operating Committee dated March 7,1986 Chugach Electric Association letter to Alaska Intertie Operat- ing Committee dated March 10,1986 Municipal Light and Power letter to Alaska Intertie Operating Committee dated March 18,1986 Alaska Intertie Operating Committee letter to Municipal LightandPower(identical letters to other Participants)dated March 4,1986 Alaska Power Authority letter to Alaska Intertie Operating Committee dated March 14,1986 Electric Power Dispatcher Training Workshop -Course Outline Draft Proposal to Intertie Operating Committee,"System Analysis and Data Base Management" Draft Proposal to Intertie Operating Committee,"Evaluation of Geomagnetic Disturbances On The Anchorage-Fairbanks Trans- mission Intertie" Attendance list from March 19,1986 Intertie Operating Commit- tee meeting. Proposed Intertie Operating Committee Budget for FY87. 3928/591(8) ALASKA INTERTIE ---FY8?7 OPERATING BUDGET ---APRIL 9,1986 ALASKA INTERTIE OPERATING COMMITTEE FY87 OPERATING BUDGET (1) SUBCOMMITTEE PURPOSE AMOUNT Dispatch/Training Operating Procedures Manual $10,000 Dispatch/Scheduling Reliability/Criteria System Analyses &Data Base $100,000 SCADA/Comm./Metering Management,Evaluation of Geamagnetic Disturbances oan the Alaska Intertie Handbook/Procedures Drafting &Supplies for $5,000 Operating Committee Handbook Machine Rating Drafting Generation Standards $10,000 Manual -Assembly &Review Reserves/Loadshed Review &Coordination of $5,000 Loadshedding (2)Secretarial Services $12,000 TOTAL $142,000 NOTES: (1)As revised at Intertie Operating Committee meeting of March 19,1986. (2)Cost associated with Operating Committee NX GOLDEN VALLEY ELECTRIC ASSOCIATION INC.Sox 1249,Fairbanks,Alaska 99707 Phone S07-452-151 April 4,1986 John Aspnes 233 Duckering Bldg. University of Alaska Fairbanks,Alaska 99775 Subject:Comments on "Revised Final Report Dynamic Stability Study of Anchorage-Fairbanks Interconnected Power Systems" 1.Due to the way the GHS transformer is modeled,138 34¢69thevoltagesatGoldHillaredifferentthante7cwhatwenormallysee.We normally have the 138 at 0.79 PU and the 69 at 1.03 PU (they «13.8 have the 138 at 1.005 PU and the 69 at 0.99 PU).This will have only a minor effect on SVS the study.The SVS regulates the 69 KV side. 2.It is unlikely to see the FMUS tie zeroed asa typical operatingcondition.Depending on the power being shipped,this could have some effect. 3.There appears to be a discrepancy in Case 2.The summary shows relaying at +=0.250 seconds and instability at +=0.570 seconds. The plots show structure at +=1.250 seconds and instability at +=1.570 seconds.Probably just typos.If I'm right,the relay action would be third zone at Gold Hill which I don't believe is modeled properly (our third zone looks towards Fairbanks).I can't believe only the Anchorage relay saw it. 4.Case 4 may have relaying problems also.I expected our voltages to recover much faster (stays down about 0.8 PU).Looking more closely at the Anchorage system shows that the fault is never actually cleared.I suspect this case is invalid due to lack of CEA relay data. 5.Power flow shows undervoltage from ELP on down to JCS (-10%at JCS).Apparently nothing was done to get realistic voltage in this area.Whole system averages .97 PU. 6.Most stability runs start out with FWS at 0.85 PU!I don't 'think the conversion from power flow loads to stability loads were properly done.. BOtUEN VALLEY ELECTRIC SSOCIATION INC. April 4,1986 Page 2 7.Cases 6 &8 both claim that the SVS prevents load Without SVS,frequency drops below 59 Hz.With SVS, drops only to 59.6 Hz.(When the tie opens,we were 45 MW)I don't think I believe this! 8.In summary,the report says we should re-examine load shedding schemes and relaying,both of which are major engineering projects.I'm surprised they would make this statement without pointing out explicitly the problems they saw that motivate these studies. LbAG,LeRobertOr Manager of System Operations ec:Henri Marvin Operating Committee shedding. frequency UNIVERSITYOF ALASKA-FAIRBANKS Fairbanks,Alaska 9970] ALASK*®2 ALASKA REIT A Mr.Robert Orr ;Manager of System Operations'86 ABR 216A\RERE21 All 18 Golden Valley Electric Association,Inc. Box 1249 Fairbanks,Alaska 99707 Dear Bob: Your detailed review of the revised final report titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System"is appreciated.The following comments are in response to the items in your 4 April 1986 letter. 1.It is assumed that the statement in your item 1 which indicates a normal 0.79 pu voltage on the 138 kV bus at Gold Hill is a typographical error. 2.Items 1 and 5 in your letter show concern about bus voltages used in the stability study.If GVEA and other utilities will provide system voltage profiles and special operating conditions, such as using a North Pole unit for Var generation,these data will be used to refine the data base for future system analyses. 3.Regarding your item 2,if a different MW flow between FMUS and GVEA is more appropriate,I assume that this information will be made available. 4.Your assumption that typographical errors exist on page 28 of the revised final report is correct.The last two times listed should be 1.250 and 1.570 seconds. 5.Items 3 and 4 in your letter refer to relay operations that you apparently don't think are reasonable.We have never received a hard copy of GVEA relay data.Henri Dale provided this information directly to the data base and we had no reason to doubt its validity.It has been recognized by both CEA and ourselves that we do not have complete relay information from CEA.It has been promised,however,and I expect that it,as well as a hard copy of the GVEA relay data,will be available forfuturework. 6.Regarding your item 6,the power flow solution,which provides initial conditions for the stability analyses,uses constant power Joads.The stability analyses use a constantimpedanceloadmodel.This is the traditional way to modelStabilityanalysisloadsand,since no measured railbelt electrical load characteristics were provided,we believe thatthisisthemostappropriateloadmodeltouse.We are not aware UNIVERSITY OF A_ASKA-FAIRBANKS that.any utilities in Anchorage or Fairbanks have accurate load characteristic data.If constant power loads are used for stability analyses,the same initial conditions 'should exist through the SVS model initialization.Constant power loadsshouldalsogivemoreunstablesimulationresultsifusedinstead of constant impedance loads.In any event,accurate load models would settle the issue raised in your item 6.This requires load characteristic information. 7.Item 7 in your letter shows concern about final report case 6 and case 8 results.These may be explained by comparing bus voltage magnitudes in Figure 7C and 8C,and in Figures 9C and 10C.In cases 5 and 7,with the SVS units off-line,bus voltages north of the faults rise significantly above 1.0 pu.Since high system voltages me 1a power requirements in the constantimpedanceloads,/R);the Fairbanks area generatorsexperiencea'arse decclerating torque due to the mismatch between input mechanical power to the generators and output electrical power required by the system.A system frequency decline is then inevitable,resulting in load shedding until power balance is again achieved. With the SVS units on-line however,the large Fairbanks area overvoltage is eliminated and,in fact,undervoltages initiallyexist.This reduces the constant impedance load ,requirements,again because load power is proportional to y2 »and thussignificantlyreducedgenerator'input power-output power unbalance.This lessens generator deceleration and,therefore, system frequency decline. 8.Regarding your item 8,it seems obvious that when two large(for Alaska)power systems are interconnected for the first time,the affected utilities would find re-evaluation of load shedding and relaying to be an important consideration. 9.In conclusion,'if your concerns are to be addressed in futuresystemanalyses,we need to be supplied with complete relayingdata,system voltage profiles and load characteristics. Sincerely, Qopres John Aspnes,Head Department of Electrical Engineering539DuckeringBuilding University of Alaska Fairbanks,Alaska 99775(907)474-7137 cc:Operating Committee Laurie Oppel Marvin Riddle Henri Dale trate oeioeipi a diibiermil lk URFERAILING CUMML PETESPautlehmtlbbatiktdi FUT IN MEW FAGE 1 OF 7 DATE HANDBOOK FORMAL ACTIONS 19/82 oo ELECTION OF OFFICERS OO B/19/B6 CORRESPONDENCE FROCEDURES 4/13/85 NO FORMAL ACTIONS 5/18/83 NO FORMAL ACTIONS 6/15/85 ADOFTED HANDBOOK FORMAT AND GUIDELINE LISTING 7F/I3/B8S Ss ADOPTED COMMITTEE DESIGNEE LISTING 7/TS/83 _)OADOF TED REVISED GUIDELINES FUR HANDEQOK 7/13/@Z ADOPTED SUBCOMMITTEE REVIEW LISTING S/i1/83 ADOPTED FIRST SCADA/METERING "INTERTIE METERING RECUIREMENTS 8/11/83 __ _ADOFTED G/C/A FROFOSAL INTERTIE RELAYING AND FROTECTION 9/BE/BS ADOFTED COMMITTEE FOSITION ON RESERVES 9/22/83 8 ADGF TED MACHINES/RATINGS UNTFORM RATING FORMS 10/20/85 ADOPTED SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE RECOMMENDATION ON COMFUTER TO COMPUTER DATA LINE STANDARDS O/20/83 ADGPTED COMMITTEE GUIDES 2.3.4.5 11/17/82 **NO DECEMBER 1983 NO FORMAL ACTIONS MEETINGKX 1/11/84 NO FORMAL ACTIONS 2/15/84 READOPTED GUIDES 2,3.4.5 AND ADOPTED A GUIDE INDEX 2/15/84 ADOPTED $10,00 FUNDING REQUIREMENT FOR MACHINES/RATINGS SUBCOMMITTEE HANDBOOK FREPARATION Z/21/B4 ADOPTED FIRST COMMITTEE BUDGET RECOMMENDATION TO ALASKA FOWER AUTHORITY IN AN AMOUNT OF #183.299 B/21/84 REINSTATED SAME OFFICERS FOR ONE MORE YEAR 4/18/84 ____ADOFTED GUIDES 1,6 . 4/18/84 __|ADOPTED REQUEST TO 4.F.A.FOR SFINNING RESERVE AND LOADSHED STUDY 5/9/84 _ADOPTED REWRITE OF N.E.R.C.GUIDE NUMBER 16 (9/84 |____-ANOPTED DRAFT OUTLINE OF MACHINES/RATINGS HANDEOOK 6/14/84 NO FORMAL ACTIONS 7/12/84 NO FORMAL ACTIONS eure.muha Ur PHe eiAaSsta [MIERTIE OFS RATING COMM©tTes FUT IN NEW HAND ROOE.FORMAL ACTIONS FORMAL ACTIONS PAGE 2 OF &DATE a or9/20(88) *¥XNO AUGUST OR SEFTEMBER 1984 MEETINGS** 10/11/84 ADOFTED SCADA/METERING/COMMUNICATIONS-DISFATCH/SCHEDULING SUBCOMMITTEES RECOMMENDATION ON "MINIMUM INTERTIE OPERATING REQUIREMENTS" 11/15/84 ADOPTED REVISTON TQ U.A.F.DYNAMIC STABILITY STUDY FROFOSAL 11/is(Be) ti?188) ADDED HARRY GECK TO THE RELIABILITY/CRITERIA SUBCOMMITTEE ADOFTED SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE RECOM- MENDATION ON "SIGN CONVENTIONS" I2V/iIB/BA NO FORMAL ACTIONS 1/18/65 _Ss ADOFTED G/C/A 12/51/84 "ANCHORAGE/FAIRBANKS INTERTIE DATA LINK REQUIREMENTS" 1/18/85 ADOPTED N.E.R.C.GUIDE #10 AND N.E.R.C."CONTROL FERFORMANC CRITERIA" 2/14/85 cece eee ADOFTED COMMITTEE RESOLUTION "AGAINST”GLE.RECOMMENDATION ON HEALY FLANT LIMITATIONS ON HEALY S.V.S.STARTING 2/14/85 ADOFTED RECOMMENDATION TO UFGRADE THE G/C/A "ANCHORAGE/FAIRBANES INTERTIE DATA t.INK REQUIREMENT(OF 12/31/84)"TO REFLECT THE ML&F/GVEA VENDOR SFECIFICATIONS : 3/21/85 ss ELECTION OF A NEW SLATE OF UFERATING COMMITTEE OFFICERS 3/21/85 |_ss ADOPTED A MOTION TO HAVE @.F.A.DIRECT G/C/A TO DEVELOF LOSS TABLES FOR THE INTERTIE 4/17/85 __ss ADOPTED MOTION ON FOWER FLOW CASES FOR INTERTIE CONTINGENCI $/15/85 ADOPTED MOTTON ON ALASKA SYSTEMS COORDINATING COUNCIL 3/15/85 6/12/85 7/10/85 PFLO/ES 7/10/85 8/14/85 *4NO SEF TEMBER 19RS COORDINATION WITH THE OPERATING COMMITTEE ADOPTED MOTION FOR NORTH/SOUTH SO/E0 SHARE ON M.1.T.C.R. INTERIM COSTS NO FORMAL ACTIONS READOPTED 2183.399 OFERATING COMMITTEE BUDGET ADOFTED A MOTIOM THAT GFERATING FROCEDURES CONTAIN DATES INDICATING DATE OF ADOFTION.INCLUDES TRANSMISSION LOSS STUDY DONE RY IRY/CLA "ANCHORAGE /FAIRBANES "ALASKA INTERTIE OFERATING ADOFTED MOTION TQ CHANGE NAME OF INTERTIE OFERATING COMMITTEE"TO COMMITTEE” COMMITTEE CONCURRENCE WITH UNDERFREQUENCY LOADSHED FLAN FRESENTED BY JOHN MARSHALL (NOT A FORMAL ACTION) MEETING < eae FET fl MEW DATE HARCEOOE. 10/9/85 oe ee 10/9/85 - 10/9/85 11/13/85 *¥KNO DECEMBER 1985 1/15/86 1/15/86 HELF REQUEST FROM COMMITTEE A.DID COMMITTEE EVER ADOFT BR. rucbh Lega DID COMMITTEE EVER ADOFT A HANDBOOK Lr He estore tietinm kin tupreies|didkts CoJPL |PEE irlFORMALACTIONSFAGE°OF ADOFTED GUIDE #4¢(TIME ERROR) ADOFTED ALASKA INTERTIE HOURLY DATA AND SUMMARY SHEET REVIEWED.REVISED AND ADOFTED FARTICIFFANT AND SUBCOMMITTEE LISTING ADOFTED GUIDE #6¢(VOLTAGE,REACTIVE CONTROL) (SCHEDULED TNTERCHANGE) AND GUIDE #3 MEETING ADUFPTED "TEST STANDARDS FOR INTERTIE METERING” ADBFTED BI-MONTHLY MEETING SCHEDULE BEGINNING 3/32/96 MEMBERS: THE "DATA ROOK"? MANUAL BEYOND "FORMAT"CONCEPT? ALASKA INTERTIE PROJECT CONTRACT AGREEMENT OPERATING COMMITTEE OUTIES AND RESPONSIBILITIES PER 8-15-85 DRAFT THE AUGUST 15,1985 DRAFT OF THE ALASKA INTERTIECANCHORAGE/FAIRBANKS)AGREEMENT ESTABLISHES AN "OPERATING COMMITTEE"UNOER ARTICLE 9 OF THE MAIN BOOY OF THE AGREEMENT ANO VARIOUS SECTIONS OF THE MAIN AGREEMENT ,THE AODENDUMS1 (RESERVES ) ANO EXHIBIT A REFER TO THE OUTIES AND RESPONSIBILITIES OF THE OPERATING COMMITTEE.THE FOLLOWING IS A LISTING OF THE PAGES ,ARTICLE/SECTIONS AND BRIEF DESCRIPTION OF THE AREAS WHICH INVOLVE THE OPERATING COMMITTEE: PAGE 4,3.1.4,CONTROL OF TIME ERROR. PAGE 4,3.1.7,ESTABLISHING VOLTAGE LEVELS. PAGE S,3.1.9.2,SCHEDULEOQ/ACTUAL POWER ANO ENERGY DELIVERIES. PAGE 6,3.1.11,LOG SHEETS AND OTHER RECORCS. PAGE 6,3.1.11,DATA FROM METER REGISTRATIONS ANO OTHER SOURCES. PAGE 6,3.1.12,ADOITIONS/MOOIFICATIONS TO ESTASLISHED SCHEDULES. PAGE 7,3.2.3,COORDINATED LOAD SHEDDING. PAGE 7,3.2.4,COOROINATED RELAYING AND CONTROL DEVICES. PAGE 7,3.2.5,REGULATION OF REAL ANDO REACTIVE POWER FLOW. PAGE 11,7.2.1,ESTABLISHMENT OF "MITCR”. PAGE 12,7.3,MOOIFICATION OF THE MINIMUM INTERTIE TRANSFER CAPABILITY. PAGE 12,7.4.1,MODIFICATIONS AND ADDITIONS TO THE INTERTIE(OESIGN ANO CONST). PAGE 13,7.4.2,COSTS RELATEO TO MODIFICATIONS AND AODITIONS. PAGE 13,7.4.3,OETERMINATION OF OIRECT BENEFITS. PAGES 17 THROUGH 21,ESTABLISHMENT OF THE "OPERATING COMMITTEE”. PAGE 23,10.2.1,OPERATION OF THE INTERTIE SUSPENSION OF WORK. PAGE 24,18.3.1,BUOGET FOR OPERATION OF THE INTERTIE. PAGE 26,11.1.1 ANDO 11.1.2,AML&8P ANO GVEA SCHEOULING RESPONSIBILITY. PAGE 27,11.2.5,MOOIFICATION OF POWER ANO ENERGY SCHEOULES. PAGE 29,13.1.3,APPROVAL OF INTERTIE RELATED METERING. PAGE 29,14.1.1,DETERMINATION OF INTERTIE TRANSMISSION LOSSES. PAGE 33,17.1,VERIFICATION ANDO APPROVAL OF PARTICIPANT INSURANCE REQUIREMENTS. PAGE 3S,17.3.2,PROOF OF INSURANCE. PAGE 39,25.1.2,NOTICES ANDO REQUESTS OF A ROUTINE CHARACTER. PAGE 2,ADDENDUM $1,A-I.1.2,RESERVE CAPACITY OBLIGATION. PAGE 2,AQDDENOUM #1,A-1!.1.3,ANNUAL ACCREDITED CAPABILITY OETERMINATION. PAGE 2,ADDENDUM #1,B-2.1.1 ,SPINNING AND NON-SPINNING RESERVE. PAGE 2,ADDENDUM $1,B-2.1.2,MODIFICATIONS TO OPERATING RESERVES ,ETC. PAGE 3,AODENOUM #1,B-2.2.3,MODIFICATIONS OR CHANGES TO GENERATING UNIT CAPABILITY FOR OPERATING RESERVES. PAGE 3,ADDENOUM #1,B-2.3.1,ALLOCATION OF OPERATING RESERVES. PAGE 4,ADDENDUM #1,8-2.4.2,SPINNING RESERVE THROUGH AUTO LOAD SHEOOING. PAGE 4,ADDENDUM #1,B-2.4.3,ASSURANCE OF SYSTEM OPERATING RESERVE. PAGE S,EXHIBIT A,OEFINITION #29,OPERATING COMMITTEE. PAGES 1 ANDO 2,EXHIBIT 0,MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS DET- MINATION. UTILITY PARTICIPANTS®REPRESENTATIVES ANO THEIR ALTERNATES WHO SIT ON THE OPERATING COMMITTEE ARE ENCOURAGED TO THOROUGHLY REVIEW THE LATEST DRAFT AGREEMENT ANO BECOME FAMILIAR WITH THE PROVISIONS OF THE AGREEMENT WITH EMPHASIS ON THE DUTIES ANO RESPONSIBILITIES OF THE OPERATING COMMITTEE. School of Engineering UNIVERSITY OF ALASKA.FAIRBANKS Fairbanks,Alaska 99701 April 14,1986 Mr.John Cooley Alaska Intertie Operating Committee Anchorage Municipal Light and Power 1200 East First Street Anchorage,AK 99501-1685 Dear Mr.Cooley: Enclosed are two proposals by Drs.John D.Aspnes,B.David Spell,and Professor R.P.Merritt entitled "Evaluation of Geomagnetic Disturbances on the Anchorage-Fairbanks Transmission Intertie"and "System Analyses and Data Base Management". It is our hope that you will favorably consider these proposals for funding. Sincerely,fL-OILSUpThomasD.Roberts,Director Institute of Northern Engineering TDR:cmo Enclosure SE.86.47 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE EVALUATION OF GEOMAGNETIC DISTURBANCES ON THE ANCHORAGE-FAIRBANKS TRANSMISSION INTERTIE by Institute of Northern Engineering University of Alaska-Fairbanks Fairbanks,Alaska 99775-1760 March 1986 4y { VyVetAtenos-Lhane J he, Jékeh D.Aspnes ',1.0.Roberts,Director Principal Investigator f"institute of Northern Engineering yl .P.Me tt Co-Investi§jator TABLE OF CONTENTS INTRODUCTION...2....ceceeeesceeces ccc meee cee enccsvcccece eee PROJECT JUSTIFICATION AND SCOPE...........0ceeee eee cceecccece . DESCRIPTION OF DATA CHANNELS......cece cece wee cece ccc nc cence SCHEDULE...cece cece cece cece cece ees c cee ec eects e ee ceeceseuses REFERENCES.....cece cere esc eeeccceccccceescesescecs se eccccccee BUDGET........eeee oseeee eee oeecccesnes eocees occ eeccccccccccene 10 INTRODUCTION This proposal requests continuing support for an on-going project originally funded by the Alaska Power Authority (APA)as part of the Anchorage-Fairbanks Intertie (Alaska intertie)construction cost.The purpose of this project is to obtain operating data for the Alaska intertie related to geomagnetically-induced current (GIC)for a three-year period. Under the terms of the original proposal,APA agreed to pay for costs associated with instrumentation design,development,acquisition, installation and instrumentation software development.Actual data collection and evaluation were not considered to be part of construction,but were to become part of the intertie operating costs. The original contract between the Engineering Experiment Station (now the Institute of Northern Engineering)at the University of _Alaska-Fairbanks (UAF)will end on 1 July 1986 and the tasks described above will be completed at that time.This proposal requests support for data collection and analysis for fiscal year (FY)1987 (1 July 1986 to 30 June 1987). We assume that continuation of data collection and analysis through FY 1988 and FY 1989 will be contingent on a favorable project review by the Alaska Intertie Operating Committee near the end of FY 1987.This proposal requests $55,387 for data collection and evaluation during FY 1987. PROJECT JUSTIFICATION AND SCOPE The problem of geomagnetically induced current (GIC)interaction with power systems is a real,present-day operating consideration. Effects of GIC on electric power systems have been presented in several papers (1-17).GIC provides undesirable quasi-de excitation of power transformers with resulting excessive harmonic generation,var flow, voltage fluctuations,variations in power flow because of voltage changes,frequency shifts due to modified power flow,possible system _instability due to frequency changes,transformer overheating,incorrect protective relay operation and increased transformer audio noise output. -l- Although GIC effects are qualitatively known,GIC interaction with power systems is a nonlinear problem that is not yet well quantified. Recent notable examples of GIC power system disturbances were in October 1980 and April 1981.These disturbances included a temporary interruption of service in a new 740 km (466 mile)500 kV transmission Tine between Winnipeg,Manitoba and Minneapolis-St.Paul,Minnesota. James Bay,Canada,experienced two 735 kV transformer failures following a geomagnetic storm in December 1980.Thus,GIC has more than academic interest to electric utilities.GIC may be responsible for significant economic losses. Very little work has been done to determine how GIC affects relay circuits (14).One reported cause of relay misoperations is the interpretation of harmonic currents as zero-sequence or negative-sequence currents.Third harmonics have a zero phase sequence and fifth harmonics a negative phase sequence.Zero-sequence and negative-sequence relays have been observed to operate during geomagnetic storms (15),probably because of harmonic generation produced by GIC excitation of power transformers.Unexplained relay trips have occurred on the existing Healy-Fairbanks transmission line. These were probably caused by GIC,but instrumentation was not in place at the time to verify the cause. The purpose of this project is to obtain operating data for the Anchorage-Fairbanks transmission intertie related to geomagnetically induced current for a three-year period.The data will be analyzed to determine the effect of GIC on transformer real and reactive power requirements,transformer audible noise,relay circuits and intertie reliability.Outages caused by GIC will be identified,as will critical GIC threshold magnitudes relating to unscheduled relay operation. It is probable that geomagnetic storms will adversely affect the proposed intertie.This observation is based on data collected at the Gold Hill substation located at the northern end of the existing Healy-Fairbanks 166km transmission line (11,14)and on reports of GIC outages and equipment failures elsewhere in North America.This project is intended to quantify GIC effects on the Alaska intertie.This will provide a better understanding of GIC-power system interactions,thus determining actual mechanisms for unscheduled service interruptions -2- attributable to geomagnetically induced current.Resulting data analysis is expected to define changes in protective relaying systems, if necessary,and determine specific needs for GIC mitigative measures. An additional project objective is comprehensive documentation of project activities and results.The Alaska Intertie Operating Committee will be kept informed of all aspects of the project and will receive at least one formal report per year,as well as the final project report. Results will also be disseminated in appropriate scientific and engineering journals,and by media releases with credit given in each instance to the Alaska Intertie Operating Committee and the Alaska Power Authority for their support. DESCRIPTION OF DATA CHANNELS The following data are proposed to be gathered and analyzed for a three-year period. 1.Real power (P watts)and reactive power (Q reactive volt-amperes or vars)required by the three-winding 60-80-100 MVA transformer at the Gold Hill substation near Fairbanks.This will be correlated with geomagnetically induced current (GIC)activity taking into account the existing AC load.This AC load will also include the static var system (SVS)supplied by the delta-connected tertiary windings. Neutral current in the grounding cables for grounded wye 138kV and 69kV windings at the Gold Hill 60-80-100 MVA transformer and for the grounded wye 138kV winding of the generator transformer at Healy.These three neutral current data channels will completely specify quasi-DC (GIC)currents in the Gold Hill power transformers and in the intertie,excluding the Fairbanks side of the Gold Hill transformer.Measuring two of three neutral currents specifies the third (at the intertie's southern end). Current driving a)distance relay,b)overcurrent/directional relays. H-component of earth magnetic field at College,Alaska. Audible noise output of Gold Hill transformer. Earth surface potential (earth current). Primary,secondary and tertiary winding voltages of Gold Hill transformer. Gold Hill transformer temperature. Line currents to primary,secndary and tertiary windings of Gold Hill transformer. The following data channels will be sampled at approximately 0.5 Hz rate (20 channels): a)Gold Hill transformer 138kV winding 3-phase watts b)Gold Hill transformer 138kV winding 3-phase vars c)Gold Hill transformer 69kV winding 3-phase watts d)Gold Hill transformer 69kV winding 3-phase vars e)Gold Hill.transformer 13.8kV winding 3-phase watts f)Gold Hill transformer 13.8kV winding 3-phase vars g)Gold Hil]transformer 138kV winding grounding current modified by low-pass filter h)Gold Hill transformer 69kV winding grounding current modified by low-pass filter i) Earth-surface potential (earth current) j)Healy generator transformer 138kV winding grounding current modified by low-pass filter k)Gold Hill distance relay current 1)Gold Hill overcurrent/directional relay current m).H-component of earth magnetic field n)Gold Hill transformer 138kV winding voltage -4- 0)Gold Hill transformer 69kV winding voltage p)Gold Hill transformer 13.8kV winding voltage q)Gold Hill transformer temperature r)Gold Hill transformer 138kV winding line current s)Gold Hill transformer 69kV winding line current t)Gold Hill transformer 13.8kV winding line current The 2 kHz frequency spectra of the following variables will be recorded: a)Overcurrent/directional relay current b)Gold Hill transformer 138kV winding grounding current c)Audible noise from Gold Hill transformer The data specified will allow determination of the effects of geomagnetically induced current on key elements of the operating intertie,namely a power transformer and several relay systems.[This is significant to utilities relying on the intertie and to the APA because it will provide information unique to this particular system regarding transformer real and reactive power requirements as a function of GIC. GIC may have a significant effect on transformer service life and will have a definite impact on intertie electrical characteristics.It is important to know how closely and how often relay current and associated current harmonics approach or exceed relay set points during periods of high GIC.It is possible for relays with harmonic restraint to be incorrectly inhibited during geomagnetic storms.Conversely, zero-sequence and negative-sequence relays have operated under similar conditions,probably because of increased third and fifth harmonics. Thus,the ultimate objective of this project is to measure the impact geomagnetic storms have on the Alaska intertie and,having quantified that impact,determine specific GIC mitigation measures or system operating procedures needed to avoid improper relay operations or severe system disturbances. Timetable July 1986 1986 -1989 July 1989 SCHEDULE Tasks Begin data collection and evaluation. Continue data collection and evaluation.Provide Alaska Intertie Operating Committee and Alaska Power Authority with annual reports. Project termination.Submit final report to Alaska Intertie Operating Committee and Alaska Power Authority. -6- REFERENCES Albertson,V.D.,and J.A.Van Baelen,"Electric and Magnetic Fields at the Earth's Surface due to Auroral Currents",IEEE Transactions on Power Apparatus and Systems,Vol.PAS-89,pp.578-584,April 1970. Aspnes,J.D.,R.P.Merritt and S.-I.Akasofu,"Harmonic generation in transformers related to 0C excitation and system loading,"IEEE Transactions on Power Apparatus and Systems,Vol PAS-100,No.2,pp 1845-1851,April 1981. Mohan,N.,J.G.Kappenman and V.D.Albertson,"Harmonics and switching transients in the presence of geomagnetically-induced currents,"IEEE Transactions on Power Apparatus and Systems,Vol. PAS-100,No.2,pp.585-593,February 1981. Albertson,V.D.,J.G.Kappenman,N.Mohan and G.A.Skarbakka, "Loadflow studies in the presence of geomagnetical ly-induced currents,"IEEE Transactions on Power Apparatus and Systems,Vol. PAS-100,No.2,pp.594-607,February 1981. Bolduc,L.,and J.Aubin,"Effect of direct currents in power transformers:Part I,A general theoretical approach,Part II, Simplified calculation for large power transformers,"Electrical Power Systems Research,Vol.1,pp.291-304,1978. Kappenman,J.G.,V.D.Albertson and N.Mohan,"Current transformer and relay performance in the presence of geomagnetically-induced currents,"presented at the IEEE 1980 Summer Power Meeting, Minneapolis,MN,IEEE Paper No.80 SM 646-0. Albertson,V.D.,J.M.Thorson,Jr.,R.E.Clayton and S.C.Tripathy, "Solar-induced-currents in power systems:Cause and effects,”JEEE Transactions on Power Apparatus and Systems,Vol.PAS-92,pp. 471-477,March/April 1973. 10. ll. 12. 13. 14. 15. ACRES Consulting Services,Limited,"Study of the Disruption of Electric Power Systems by Magnetic Storms,"Dept.of Energy,Mines and Resources,Ottawa 3,Ontario,March 1975. Lanzerotti,L.J.,ed.,"Impacts of Ionospheric/Magnetospheric Processes on Terrestrial Science and Technology,"prepared for the Panel on Solar System Plasma Processes of the Study on Space Plasma Physics,Space Science Board,National Academy of Sciences,April 1977. Masson,L.,and J.R.Valotaire,"Investigation of the effects of solar induced DC in H.V.power transformers,"presented at the Canadian Electrical Association Fall Meeting,Calgary,Alberta, October 1974. Akasofu,S.-I.,and R.P.Merritt,"Electric currents in power transmission line induced by auroral activity,"Nature,Vol.279, pp.308-310,24 May 1979. Boerner,W.-M.,,et al.,"Impacts of solar and auroral storms on power line systems,"Proceedings of the 5th International Wroclaw Symposium on Electromagnetic Compatibility,17-19 September 1980. Pirjola,R.,"Induction in power transmission lines during geomagnetic disturbances,"Proceedings of the 5th International Wroclaw Symposium on Electromagnetic Compatibility,17-19 September 1980.; Aspnes,J.D.,and S.-I.Akasofu,"Effect of solar induced current on autotransformer tertiary windings,"IEEE Transactions on Power Apparatus and Systems,Vol.PAS-101,No.3,pp.635-637,March 1982. Albertson,V.0.,,J.G.Kappenman and N.Mohan,Discussion of reference 14,IEEE Transactions on Power Apparatus and Systems, Vol.PAS-101,No.3,pp.638,March 1982. 16. 17. Aspnes,J.0.,and R.P.Merritt,"Effect of OC Excitation on Instrument Transformers,"IEEE Transactions on Power Apparatus and Systems,Vol.PAS-102,No.11,November 1983. Akasofu,S.-I.,and J.D.Aspnes,"Auroral Effects on Power Transmission Line Systems,"Nature,Vol.295,No.5845,pp. 136-137,14 January 1982. A. BUDGET 1 July 1986 to 30 June 1987 SALARIES 1.Principal Investigator,J.Aspnes4wks@$36.06/hr 2.Principal Investigator,R.Merritt 3 wks @ $42.17/hr 3 Principal Investigator,D.Spell 4.5 wks @ $27.10/hr 4.Secretary1wk@$12.49/hr 5.Graduate Research Students 1300 hrs @ $10.00/hr LEAVE BENEFITS 1.16.1%of A.1,A.2 and A.3 2.18.3%of A.4 STAFF BENEFITS 1.24.6%of A.1,A.2,A.3 and B.1 2.26.6%of A.4 and B.2 TRAVEL SERVICES 1.Documentation and report preparation 2.Telephone 3.Computer time EQUIPMENT (contingency) OVERHEAD 1.39.2%MTDC (Direct less Equipment) TOTAL -10- |42.182100SHEETSi.aALASKA INTERTIE QPERATIVE PPRIL 23,1986 HARRY BECK Let Prove: (ay Donen Foln .Magshat! din tall Tehn £ JUKE /USSp/ Lacey CelpShowSiecakhust Tour)SPenice- Nas eer DRdouMathai fun Lebel As PNE Si.L.tnobitCOMMITTEE 2t/-7269 P6/--Dalry £64-07897 S6Y-O60% 745-323) 263 SISO Ved Ys6 - s/1CE& $207 F4HS-DYS/ S6¢-077¢ YS?-ISS | 225-3lo] SSTI--b6722 YY -L098 ALASKA (NTERTIE QPLERATING COMMITTEE APRIL 23,1986 2a|42-182100SHEETSMadeinU.S.AONnaALwartHARRY BECK APA 2b /-7269 Leh YPayri §'"oC/-Dary (ay Doucen CEA $64-O789 Joly.Magshah CA S6Y-O60% Jin all MER 745 Se *I Tehyn §MlP 263 SYO JUKE PIASSff /7L0P 2@ G2LU Larey Cel My S Uso 5/68 Show Siecaktust (PPL TtS-DGS/ Jed)SP CLA S6t-077¢ KReaeer GRC LVEA YSS-ISS-| day atthe,ACCT /HEA 235-91]pan Va aveA YSST-b6722 Tons Asenes UAF 474 -L028 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,MAY 21,1986 BEGIN at 9:00 A.M. I.Adoption of prior meeting minutes Il.Approval/modification of agenda III.Committee correspondence and reports A,Dispatch/Scheduling Subcommittee B.Reliability SubcommitteeC.Intertie Status Update (A.P.A.) D.Proposed Operating Committee Manuals Updating IV.Visitor comments related to items on agenda V.Old Business VI.New Business A.Recess and work station B.Dispatcher/Scheduling C.Reliability D.Intertie Operating Committee Manuals consolidation E.Insurance F. Intertie Budget FY87 G.Others VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Meeting location:Alaska Power Authority Executive Conference Room 701 E.Tudor Road Anchorage,Alaska(907)561-7877 3928/591(1) |1K Parrs |pier Rech Duron a Feld, ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,MAY 21,1986 BEGIN at 9:00 A.M. ei.Adoption of prior meeting minutes vil.Approval/modification of agenda III.Committee correspondence and reports "K. Dispatch/Scheduling Subcommittee B.Reliability Subcommittee -preyesa/om Th fortin foss7C.Intertie Status Update (A.P.A.) D.Proposed Operating Committee Manuals Updating IV.Visitor comments related to items on agenda Vv.Old Business -Lecve/of rnin hes -SPY sane free O16toAyre.Aamebee?mira Pry -AM SefVI.New Business ; A.Recess and work statton sess en .nSBi.Dispatcher/Scheduling -norhentemrsat Si bev!teritaes 1a Ine,-C.Reliability -D.Intertie Operating Committee Manuals consolidationc=. Imsurance -/9 S64f /asermee,LianFy ,Par ant?F.Intertie Budget FY87 p77 oeG.Others Myer Cela FY 5%,butlget VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments y.,,2%A er nh ASA ,Re lisbi by -Osta B80,eed 6/4.IX.Adjournment Cem pow Meeting location:Alaska Power Authority (=AyExecutiveConferenceRoomJua/&Oc.aa 701 E.Tudor Road 12m. Anchorage,Alaska(907)561-7877 Goer bot "39,975 By sthsk hai costs Lu ple sFro/"A OP-3 rec ml rar DF,Ps vee. 3928/591(1) Record CopyFile#ANE Pes 3-4 Alaska Intertie Operating Committee Wednesday,March 19,1986 (At Anchorage Municipal Light &Power) Attendance: Sam Mathews Alaska Electric &Generation Cooperative Jim Hal]Alaska Electric &Generation Cooperative Harry Beck Alaska Power Authority Dave Eberle Alaska Power Authority Afzal Khan Alaska Power Authority Ed Morris Alaska Power Authority Howard Thacke Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power Larry Hembree Anchorage Municipal Light and Power Mike Massin Anchorage Municipal Light and Power Ray L.Duncan Chugach Electric Association John C.Marshal]Chugach Electric Association Larry Colp Fairbanks Municipal Utilities System Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association John Aspnes University of Alaska -Fairbanks The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Engineering Department Conference Room atAnchorageMunicipalLightandPower(ML&P). Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unani- mously. Mike Massin suggested that the agenda be amended to reflectDaveEberle's presentation at 11:00 a.m.and to include (1)Univer-sity of Alaska -Fairbanks (UAF)Dynamic Stability Study presenta-tion,(2)discussion of interconnected system collapse of March 4, 1986 and,(3)FY86 Intertie Operating Budget.Mike Massin motioned for the agenda to be adopted as amended and John Marshall seconded the motion.The motion was approved unanimously. Marvin Riddle made a presentation on the joint meeting of the Dispatch/Scheduling and Dispatch/Training Subcommittees conducted on February 12,1986 at 9:00 a.m.in the Executive Conference Room at ML&P.Minutes of the meeting were furnished and attached.He reported that the subcommittee had discussed the upcoming seminars to be provided by the UAF Electrical Engineering Department for system dispatchers.He stated that UAF would be conducting two advanced seminars only,one scheduled for the week of June 2,1986 and the other the week of June 9,1986.Finally,he commented that these sessions will be conducted by Professors Robert Merritt and George Mulligan.The course outline for the seminars is included with the minutes. 3928/591(2) Marvin Riddle stated that the scheduled outage (Feb.19-20,1986) of the Teeland -Pt.Mackenzie line required to swing towers did not occur.Ray Duncan and Marvin Riddle then discussed the next available date for a scheduled outage at Teeland required in order to complete the 230 kV conversion work.Ray Duncan stated that the earliest date available appeared to be the 3rd week of April. Ed Morris then stated that he would notify the Participants of theexpecteddateofarrivalofGeneralElectric(GE)engineer Don Homer.He said he would confirm whether a tieline outage is required while the Static Var System (SVS)at Teeland is out-of- service.Bob Orr then stated that the expected downtime for the SVS while modifications are being made to it will be two to three days. Marvin Riddle then submitted copies of the NERC Operating Guide #9 and recommended that it be adopted by the Operating Committee. Mike Massin stated that the preparation of the Intertie Manual would soon be completed.Bob Orr stated that the system operators need these operating guides in a manual form. Turning to Intertie Status Update,Harry Beck reported on the status of the preparation and completion of the Maintenance and Transmission Service Agreements for the Alaska Intertie.He noted that the Maintenance agreements were being sent to Golden Valley Electric Association (GVEA)and Matanuska Electric Association for final review and comment.He further noted that the Transmission Service Agreement was still being reviewed by the Alaska PowerAuthority(APA)and the Attorney General's office.Afzal Khan reported that the SCADA Agreement with ML&P was ready for signature by both parties.Harry Beck stated that review copies of the SCADA,Maintenance and Transmission Service agreements would be made available to all Operating Committee members pending comple- tion of the signature process. Harry Beck noted that the preliminary Alaska Intertie FY87 budget package had been prepared and distributed by the APA the previous week and that the APA would be presenting this package to the Operating Committee during work session.He further stated that Jim Hall would report on the March 4,1986 fire in the breaker at the Douglas Substation when the system outage is discussed under work session. Mike Massin then reported that Afzal Khan,Harry Beck and himself had preliminarily reviewed the material comprising the Intertie Manual.He indicated that this manual would include signed copies of all agreements relating to the Intertie.He further stated thatproceduresandoperatingguidelinesadoptedbytheOperating Committee would be retyped and installed in the manual. 3928/591(3) Mike Massin then reported that the following were the new designa- ted representatives and alternates of the Intertie Operating Committee: Organization Representative Alternate AEG&T Sam Mathews Jim Hal] APA Ed Morris Harry Beck CEA John Marshall Ray Duncan FMUS Larry Colp Allen Brailie GVEA Bob Orr Marvin Riddle ML&P John Cooley Mike Massin Ed Morris indicated that he would like to have Afzal Khan listed as the second alternate for the Power Authority if the rules of the Operating Committee allow. There were no visitors present at the meeting. There was no Old Business to consider. Under New Business,the Operating Committee went into work session at 10:10 a.m. Dr.John Aspnes,Head of the Electrical Engineering Department, University of Alaska,Fairbanks presented the results of the final report,"Dynamic Stability Study of the Anchorage-Fairbanks Inter- connected Power System."He then explained the analysis and the results for a few of the cases developed in the study.He reported that the University had successfully installed in the source code models of the SVS,underfrequency relay and reverse power relay. He stated that these models are not present in the EPRI 745 code and therefore the code developed at the University,and available to the contributing utilities,is unique.He expressed his thanks to Laurie Oppel and Henri Dale for their efforts in developing these modifications to the source code.Finally he applauded Laurie Oppel for her efforts in the completion of the study and the final report. Dave Eberle then discussed the remaining items to be completed as a part of Intertie construction and the schedule for this work.He stated that most of the remaining items would be completed duringthesummerconstructionseason.These items included (1)installa- tion of temperature sensors in the SVS cooling plenum,(2)replace-ment of beacon fixture,(3)installation of two-way flashers in beacons,(3)replacement of tower structure locknuts,(4)change out of defective bus tap connnectors on Gold Hill transformer. Dave Eberle then mentioned that General Electric (GE)was due to arrive at Teeland the following week to finish work associated with modifications to the SVS.Then GE would be ready for final 3928/591(4) testing.Dave Eberle said that GE was proposing to conduct a sim- plified loss test in which the SVS devices would be checked through their allowable range of operation.He said that the Power Author- ity was examining this alternative testing procedure.Finally,Dave Eberle stated that the problem identified as #14 (i.e.,SVS stabilizing transformer critical power)in Bob Orr's letter to the Alaska Power Authority dated November 12,1985 was apparently not clear to Power Authority staff.Dave Eberle requested clarifica- tion on this item.Harry Beck stated that he had not seen any documentation concerning this problem and that it was therefore difficult to proceed with a solution in concert with Commonwealth Associates.Bob Orr indicated that he felt the problem was already adequately documented.Mike Massin asked how this problem is eliminated at SVS installations elsewhere.Discussion continued on these questions/statements.Finally,Dave Eberle indicated that this problem and possible solutions would be explored by the Power Authority. The Operating Committee then recessed for lunch at 12:00 p.m. The Operating Committee reconvened at 1:15 p.m. John Marshall provided a brief description of the system outage of March 4,1986 from the perspective of the CEA system.Mike Massin then provided a brief description of the system outage from the perspective of the ML&P system.Bob Orr discussed the GVEA system response during this outage.Finally,Jim Hall discussed the fire in the Douglas breaker which occurred that same afternoon. Under Operating Committee Manuals consolidation,Mike Massin reported that the new manual will be put together soon and handed out to each of the designated representatives of the Operating Committee. Under Election of Officers,Bob Orr nominated John Cooley for Chairman.Afzal Khan seconded the nomination.The motion to elect was passed unanimously.Finally,Bob Orr nominated Ed Morris for Secretary.The motion to elect was passed unanimously. Under budget,Ed Morris presented addenda to the "Alaska Intertie Budget"dated March 12,1986.These addenda included a chronology and status of current budgetary obligations of the Participants. Ed Morris stated that the Intertie is still operating under the testing agreement and that a budget needs to be established prior to commencement of commercial operation.He then requested that all Participants review the proposed budget package. Jim Hall stated that the figure for MEA Transmission Service wastoohigh(i.e.,$250,000)and that he felt this figure would beshowntobeontheorderof$75,000.John Marshall said that CEA had established a budget review committee and it would be meeting 3928/591(5) on March 25,1986 to discuss the budget package submitted by the Power Authority.He added that CEA had no official comments to make at this time. Bob Orr then questioned the Teeland Substation Maintenance figureof$28,000 stating that it was high in relation to expected costs at Healy and Goldhill.Harry Beck stated that this was an old figure and was used in lieu of any new information from CEA. Bob Orr stated that the maintenance contract between CEA and the Power Authority was a start-up contract and he questioned using a cost associated with this contract for the purpose of estimating maintenance costs.Ed Morris indicated that the Power Authority would review both the existing maintenance contract with CEA and the expected costs of maintenance at Teeland. Bob Orr stated that the amount for communications operations andmaintenancewastoohigh(i.e.,$65,000).Afzal Khan explained that this figure was provided by Mike Ridge of the State DivisionofTelecommunications(DIVCOM).Bob Orr indicated that he felt an adequate amount for this service based on GVEA's experience with their own equipment was on the order of $10,000 per year.He requested that DIVCOM be requested to furnish scope and documenta- tion for these costs. Discussion then turned to insurance coverage for the line and substations.Harry Beck indicated that the Power Authority does not have insurance coverage for the transmission line itself.He indicated that only the Intertie substations and their equipment are covered by insurance.Mike Massin asked about equipment and property insurance for the 4 Dam Pool projects.Ed Morris ex- plained the provisions of insurance for the 4 Dam Pool.Bob Orr both felt that the R&R portion of the budget should be dropped and only provided for at the end of the fiscal year should the need to use R&R funds arise.Ed Morris then countered with the question as to where the funding would come from for doing this.Bob Orr stressed his concern about the lack of insurance for the trans- mission line.Ed Morris stated that the Power Authority would address this question of insurance coverage and R&R funding during the budget review period of the next few weeks. Discussion then turned to the Alaska Power Authority portion of the budget.Ed Morris explained the breakdown of this budget item. Bob Orr stated that the total amount was too high.Ed Morris indicated that a lot of these costs are allocated costs associated with operation of the Power Authority itself and that they must be recovered:that there is no provision for capturing these costs from any other source of funding other than Intertie Operations and Maintenance.Ed Morris stated that the Power Authority's costs would be reviewed in the hope of lowering these allocated amounts. 3928/591(6) Turning to the budget of the Intertie Operating Committee,costs associated with some of the subcommittees were revised.The total proposed Operating Committee Budget for FY87 is $142,000.See attached.It was the consensus of members of the Committee that studies should be funded through the committee and not through the Power Authority where allowable.The Operating Committee's authority to directly contract for services was questioned.It was decided that this question be reviewed by the Power Authority and it's legal counsel. Finally,Harry Beck asked all Participants to forward to the Power Authority their written comments on the budget package and their revised budget estimates no later than April 1,1986. Turning to Subcommittee assignments,CHairman Mike Massin directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET ON TUESDAY,APRIL 22, 1986 at 9:00 A.M.IN THE TRAINING ROOM AT GOLDEN VALLEY ELECTRIC ASSOCIATION for the purposes of reviewing the Operating Procedures Handbook and the Operating Guidelines. Under formal Operating Committee action/recommendation,Bob Orr motioned that the Operating Committee adopt the NERC Operating Guide #9,"Action In An Operating Capacity Emergency".Mike Massin seconded the motion.The motion was adopted unanimously. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,APRIL 23,1986 AT 9:00 A.M.IN THE MAIN BOARD ROOM AT FAIRBANKS MUNICIPAL UTILITIES SYSTEM AT 645 FIFTH AVENUE,FAIRBANKS,ALASKA. Larry Colp then motioned for the meeting to adjourn.John Marshall seconded the motion.The Operating Committee then unanimously adopted the motion to adjourn at 4:35 p.m. Respectfully submitted, DMSO Edwin L.Morris,Secretary Alaska Intertie Operating Committee 3928/591(7) Attachments: 1.PPWw12. 13. April meeting agenda Minutes from February 12,1986 Dispatch Scheduling -Dispatch Training Subcommittee Meeting NERC Operating Guide #9,"Action In An Operating Capacity Emergency" Golden Valley Electric Association letter to Alaska Intertie Operating Committee dated March 7,1986 Chugach Electric Association letter to Alaska Intertie Operat- ing Committee dated March 10,1986 Municipal Light and Power letter to Alaska Intertie Operating Committee dated March 18,1986 Alaska Intertie Operating Committee letter to Municipal LightandPower(identical letters to other Participants)dated March 4,1986 Alaska Power Authority letter to Alaska Intertie Operating Committee dated March 14,1986 Electric Power Dispatcher Training Workshop -Course Outline Draft Proposal to Intertie Operating Committee,"System Analysis and Data Base Management" Draft Proposal to Intertie Operating Committee,"Evaluation of Geomagnetic Disturbances On The Anchorage-Fairbanks Trans- mission Intertie" Attendance list from March 19,1986 Intertie Operating Commit- tee meeting. Proposed Intertie Operating Committee Budget for FY87. 3928/591(8) Alaska Intertie Operating Committee MARCH 19,1986 LAME [aS ied L1L 4P 263-5277 Harry BECK APA 2t/-2262 Aye 4t A wa APA PCOS F2¥& Aah Co WewaheQt CEN 46 Y-0603 "Rey LD nese CEA Sey 0187 i frre SI Lg ee eV (CL)The LACE VAM Mat 26/-7JA/E Trey Aoppiss UA Ss SoeLANHALLMERD¢5-323!Tohn -Combs mcP 263 S¥SO El Toes LA 2o/-23/4 Hs a aera Byer Ain my Cile ENMUS YSo-/000dawUetitnnAEGET|&7s-9167 W Vemence MLZP 'Llo3 -§S243 Die Ever!APA ALASKA INTERTIE OPERATING GUIDE NO.9 ACTION IN AN OPERATING CAPACITY EMERGENCY PURPOSE The purpose of this Guide is to outline basic considerations in the formulationofasystem's or pool's plan for response to an operating capacity emergency toassuremaximumassistancewhileadequately.protecting the reliability of theinterconnection.To accomplish this,a uniform understanding and approach byallsystemsandpoolsisessential. DEFINITIONS An operating capacity emergency exists when the availability of operating capacity within a system or pool,plus purchases from the interconnectedsystem,to the extent available or limited by transmission line tranSfercapability,are temporarily inadequate to meet its load demand obligations.Asystemorpoolisdeficientwhenitisunabletomeetitsnetinterchangeschedulewithoutsheddingload. GENERAL GUIDELINESA.Each system or pool shall plan to operate its generating tresources toprovideforareasonablelevelofspinningandoperatingreserveunder forecast load conditions,taking into consideration such factors as errors in forecasting,equipment unavailability,number and size of units,forcedoutageratesandmaintenanceschedules.B.A plan,consistent with NERC Operating Guides,shouldbe developed,maintained and implemented as required by each system or pool to copewithoperatingcapacityemergencies., (1)Dispatching personnel should be thoroughly trained and periodicallyupdatedintheuseoftheplan.\ (2)Dispatching personnel must have the responsibility 'and authority to implement the emergency procedures which are included in the plan. (3)Appropriate governmental agencies should be apprised of the plan soitcanbeeffectivelyimplementedwhenneeded. (4)The plan must be coordinated with neighboring utilities. Revised Approved -2- (5)The system or pool operating capacity emergency plan shall beimplementedinanoperatingcapacityemergency. C.Operating agreements between neighboring systems or pools shall contain appropriate provisions for emergency assistance,including provisions to obtain emergency assistance from remote systems or pools. D.A system or pool which is anticipating or experiencing an operating capacity emergency must communicate on a continuing basis its needs for emergency assistance and its current status to neighboring systems or pools and throughout the total interconnection.The guidelines for reporting critical system status are found in Appendix 9A.Systems able to provide emergency assistance shall make known their capabilities.The deficient system shall schedule all available assistance that is required with as much advance notice as is practical.This will permit systems and pools to assess their resources and the resources of their neighbors,and thus permit optimal assistance. E.When an operating capacity emergency occurs,a prime consideration is tomaintainparalleloperationthroughouttheinterconnectedsystems.This will permit rendering maximum assistance to the system in trouble./ Iv..OPERATING CAPACITY EMERGENCY WITHIN A SYSTEM OR POOL A.Asystem or pool experiencing or anticipating an operatirg capacity emergency shall avoid utilizing the assistance provided by the frequency bias contribution of other systems for any longer than required to accomplish the following steps 'in an expedient manner:| (1)Load its readily available operating reserve, (2)Analyze its ability to recover utilizing only its own resources,and (3)If necessary,determine the availability of readily available assistance from others and schedule the assistance into its own system. In the event the steps taken above are inadequate to restore net interchange schedules expediently,immediate action must be taken torelievethedeficiency.Steps to be implemented,as required,include butarenotlimitedto:) (1)Obtain all available emergency assistance from other systems who are willing to make emergency reserves available to prevent or mitigate the loss of firm load on the deficient system,and (2)Implement manual load shedding program on the deficient system. Revised ' Approved -3- If a transmission facility becomes overloaded and cannot be relieved byadjustinggenerationorbyothermeansandifthelossofsuchfacilitywouldadverselyimpacttheinterconnection,appropriate relief measures, including load shedding,shall be implemented immediately by the deficientsystemorpooltobringthetransmissionfacilityloadingtowithintheestablishedlimits. If a group of systems or pools becomes separated from the remainder of the interconnection,a critical high or low frequency deviation may occur. Relief measures shall be applied by any system(s)contributing to thefrequencydeviationtorestorefrequencytopermitresynchronizing. In the event that an area becomes separated during a disturbance, interchange schedules between control areas or fragments of control areas within the separated area should be immediately reviewed and appropriate adjustments made in order to gain maximum assistance in restoration. Attempts shall be made to maintain the adjusted schedules whether generation control is manual or automatic. OPERATING CAPACITY EMERGENCY IN AN ADJACENT OR REMOTE SYSTEM OR POOL.” A. B. 1 Automatic generation control should remain operative as long aspracticable. If automatic generation control has become inoperative,manual control shall be used to adjust generation to maintain schedules.Unilateral adjustment of generation to return frequency to normal,beyond that supplied through frequency bias action,may further jeopardize anoverloadedtransmissionfacility. If an overload persists on a transmission facility,the affected system or pool shall notify the neighboring or remote system or pool of the magnitudeoftheoverloadandrequestappropriaterelief.If intolerable overloadcontinuesandequipmentisendangered,the affected system or pool mayopentheoverloadedfacility.taeweeseeBmOTRevised Approved ALASKA INTERTIE OPERATING GUIDE NO.9 APPENDIX 9A CRITICAL SYSTEM STATUS REPORT VIA TELECOMMUNICATION NETWORKS It is the responsibility of any system or group of systems to inform other systems in their Region,through predetermined communication paths,whenever: 1. 2. The system is not able to operate within the NERC Criteria for Minimum Reliability,or Its status is burdening or reducing the reliability of the Interconnection. The following system conditions will warrant reporting: 1. 2. 4. A system is unable to purchase capability to meet its load and reserverequirementsonaday-ahead basis or at the start of any hour. Line loadings,equipment loadings and voltage levels are such that a single contingency could threaten the reliability of the bulk power system.L A system anticipates voltage reduction or public appeals because of an inability to purchase emergency assistance.A system has instituted voltage reduction,public sppeals or loadsheddingforotherthanlocalproblems. Revised Approved j a pore (ED 2 veeks ue Sons Electric Power Dispatcher Training Workshop DESCRIPTION The Dispatcher Training Workshop provides an intensive review ofelectricalfundamentalsandimportantcharacteristicsofpowersystem components.These topics provide background for a concluding section on power system operation.Each 5-day workshop session is scheduled for 40 hours.: SECTION 7 SECTION a. b. Cc. d. e. f. g. SECTION a. b. Cc. d. e. f. SECTION a. b. Cc. FUNDAMENTALS OF ELECTRICITY Basic electrical units defined Production of electrical energy Conductors,insulators,semiconductors 'Ohms Law.amperes,volts watts Voltage drop,regulation Magnetic fields,electromagnetic induction., - Capacitance,inductance impedance reactance Power factor,VARS metering II -FUNDAMENTALS OF POWER GENERATION Generators -3 phasePrimemovers,steam turbine,gas turbines,water turbines Boilers,tubes,superheat,reheater,condensersApplications,efficiency - Diesel generators III -GENERATORS Basic types of rotors Synchronous speed Excitation,saturation Voltage regulation Power system stability Generator connections,neutral MVA,MW,MVARS,KV IV -TRANSFORMERS Types of cores Windings,ideal transformer Turns ratio,voltage ratio,current ratioPracticaltransformers Efficiency -.e Metering,CT,PT -CIRCUIT BREAKERS Types,mechanics,oil,air,vacuum Ratings,MVA ;Reclosers,sectionalizers Py ::a |Yibatow JK rr SECTION 4.. b. Cc. vis Induction,T.0.C.Direct{onal -PROTECTIVE RELAIS .Overcurrent,over/umccr vo "1JpkLaeTSBeroarryNinwis) chert Aestk frecbtlrurif-_or And |oFIla $/)e d.:Frequency 7 :e,Zone,distance SECTION VIt CONDUCTORS Aiid LINtS a "Inductance,capacitance,iniczdins2"Spl "Wire size,type,ampacicy tt Ge.'Corona,HV : Z if 7 Bundling ..axSECTIONVIIT.-PRINT READING 4">a,Standard symbols iE.et.be Sehematie dtagrams :Sefs6.One-line diagrams.4 So 'Ba: to d.:Power interconnect diagrams -a]my ei abo)6 @.6 CB tripping diagrams |Ft be:aedesfeRelaytrippingdtagrams-qi jo wn ae ..y oe:'SECTION 1x 2)SYSTEM OPERATIONS =eycaeTransfer.Hmits |re:$tability .:.:-ose.|Power flow::Reactive compensation .nt 'Automatic generator contral pSAreacontro]error,frequency ¢error 2SCADA2ad::Power transactions:Communication at LY ae oreife lia ISygreynsFROn.tends-FAD rarenT 76 )ae re ao |PsLATION -oF.01eenweenbacle |aseteMGs1647 "xA|=im,iat4 oeBan.re a t i q seeChaneitbaelinss :woe tenes ates o,wed xT og |Dpto Lew , i ;..An Ghar oki Lins éZI Lanai comsaeVg"we Loreenec.ekilutine,tJOm a,|he.ton Golentaneiad |,mtamenwe28aan .fot : 1967922asty 38°Le codOT?80 '\ Alaska Power Authority State of Alaska March 14,1986 Afzal Khan,Secretary Alaska Intertie Operating Committee Alaska Power Authority P.O.Box 190869 Anchorage,AK 99519-0869 Dear Afzal: In response to the request for the designation of an official rep- resentative and alternate,I wish to name the following: Representative -Edwin L.Morris Alternate -Harry Beck Due to the level of other activities of the Power Authority it is likely that a second alternate will be required.If committee rules allow,I would like to assign the second alternate to be Afzal Khan. Sincerely,|, obert D.Heath Executive Director RDH/ELM/cde cc:E.L.Morris H.Beck 3462/575 PS Box *60869 "O'Bast "Uaor "oad Arcnorage Alaska 99519-0869 (907)561-7877 Ne ./RECEIVE 8Yar.cokingGOLDENVALLEYELECTRICASSOCIATIONIRbASKEx1349,"Fairbanks,Alaska 99707 Phone 907-452-1151 '86 MAR 10 All -42 March 7,1986 Mr.Afzal H.Khan Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 RE:Alaska Intertie Operating Committee Dear Mr.Khan: Reference your letter dated March 4,1986.GVEA designates Robert Orr as our official representative to the Operating Committee and Marvin Riddle as his alternate . Best regards, Michael P.Kelly General Manager ee:B.Orr ?) ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE *POUCH 6300 «ANCHORAGE.ALASKA 99502-0300 «PHONE 907-563-7494TELEX:CHUGauasneee(090125265 6 MAR 18 AQ '26March10,1986 Mr.Afzal H.Khan . Secretary,Alaska Intertie Operating CommitteeAlaskaPowerAuthorityP.O.Box 190869 Anchorage,AK 99519-0869 Dear Mr.Khan: Please be advised that Chugach Electric Association,Inc.,as a participant utility in the Alaska Intertie,designates thefollowingpersonsasofficialrepresentativestotheOperatingCommittee: John C.Marshall,P.E.,Principal Representative Ray Duncan,Alternate Representative Sincerely, .Richard Newland Assistant General Manager RN/JCM/pkd/M109 ce:Dora BrOPPGaryDockham Municipal Light &rower on 1200 EAST FIRST AVENUE -ANCHORAGE,ALASKA 99501-1685 \gine 1982,TELEPHONE (907)279-7671 \ é Tony Knowles, Mayor March 18,1985 MAR181986 ML&P/ENGINEERING Mr.Afzal H.Khan Alaska Intertie Operating Committee c/o Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 Dear Mr.Khan: As requested in your letter of March 4,1986,Municipal Light and Power has made the following designations for ML&P representation on the Alaska Intertie Operating Committee: Mr.John Cooley,Manager for the Power Management Division of ML&P will become the dsignated representative beginning with the next Operating Committee meeting after the March 19,1986 Operating Committee Meeting. Mr.Mike Massin,Manager for the Engineering Division of ML&P will become the designated alternatie also beginning with the next Operating Committee meeting after the March 19,1986 Operating Committee meeting. The designations will remain in effect until further notice. Sincere Thomas R.Stahr 42 General Manager Municipal Light &Power TRS/slg cc:John Cooley Mike Massin PROVIDE FOR TOMORROW,SAVE ENERGY TODAY. Alaska Intertie Operating Committee March 4,1986 Mr.Thomas Stahr General Manager Anchorage Municipal Light &Power -1200 East First Avenue Anchorage,Alaska 99501 Dear Mr.Stahr: The annual election of officers will be held on March 19,1986. The Operating Committee requests each participant utility to designate an official representative and alternate to the Operating Committee.We will appreciate it if your response is sent to Afzal H.Khan,Alaska Power Authority,P.0.Box 190869,Anchorage, Alaska 99519-0869,by March 14,1986. Sincerely, AW bhicn --- Afzal H.Khan Secretary Alaska Intertie Operating Committee cc:Mike Massin,ML&P 3265/DD01° Alaska Intertie Operating Committee March 4,1986 Mr.Robert Martin,Jr. General Manager Chugach Electric Association,Inc. .5601 Minnesota Drive,Pouch 6300 Anchorage,Alaska 99502-0300 Dear Mr.Martin: The annual election of officers will be held on March 19,1986. The Operating Committee requests each participant utility to designate an official representative and alternate to the Operating Committee.We will appreciate it if your response is sent to Afzal H.Khan,Alaska Power Authority,P.0.Box 190869,Anchorage, Alaska 99519-0869,by March 14,1986. Sincerely, w.bhaw-_-- Afzal H.Khan Secretary Alaska Intertie Operating Committee ce:John C.Marshall,CEA 3265/0001- Alaska Intertie Operating Committee March 4,1986 Mr.Samuel Matthews Alaska Electric Generation and Transmission Cooperative,Inc. c/o Homer Electric Association P.0.Box 429 Homer,Alaska 99603 Dear Mr.Matthews: The annual election of officers will be held on March 19,1986. The Operating Committee requests each participant utility to designate an official representative and alternate to the Qperating Committee.We will appreciate it if your response is sent to Afzal H.Khan,Alaska Power Authority,P.0.Box 190869,Anchorage, Alaska 99519-0869,by March 14,1986. Sincerely, Upper tt.bhom Afzal H.Khan Secretary Alaska Intertie Operating Committee 3265/0001 Alaska Intertie Operating Committee March 4,1986 Mr.Virgil Gillespie General Manager Fairbanks Municipal Utility System -P,0.Box 2215 Fairbanks,Alaska 99707 Dear Mr.Gillespie: The annual election of officers will be held on March 19,1986. The Operating Committee requests each participant utility to designate an official representative and alternate to the Operating Committee.We will appreciate it if your response is sent to Afzal H.Khan,Alaska Power Authority,P.0.Box 190869,Anchorage, Alaska 99519-0869,by March 14,1986. Sincerely, A.Mom-_-_-- Afzal H.Khan Secretary Alaska Intertie Operating Committee ec:Larry Colp,FMUS 3265/0001° .Alaska Intertie Operating Committee March 4,1986 Mr.Michael Kelly General Manager Golden Valley Electric Association,Inc.. .P.-0.box 1249 , Fairbanks,Alaska 99707 Dear Mr.Kelly: The annual election of officers will be held on March 19,1986. The Operating Committee requests each participant utility to designate an official representative and alternate to the Operating Committee.We will appreciate it if your response is sent to Afzal H.Khan,Alaska Power Authority,P.0.Box 190869,Anchorage, Alaska 99519-0869,by March 14,1986. Sincerely, fp¢LioAfzalH.Khan Secretary Alaska Intertie Operating Committee cc:Robert Orr,GVEA 3265/0001- IV. v. VI. VII. ALASKA INTERTIE OPERATING COMMITTEE AGENDA - WEDNESDAY,MARCH 12,1986 BEGIN at 9:00 A.M. Adoption of prior meeting minutes Approval/modification of agenda Committee correspondence and reports A.Dispatcher/Training B.Dispatch/Scheduling SubcommitteeC.Intertie Status Update (A.P.A.) D.Proposed Operating Committee Manuals Updating Visitor comments related to items on agenda Old Business New Business A.Recess and work station B.Dispatcher/Training C.Dispatch/Scheduling D.Intertie Operating Committee Manuals consolidation E F .Etection of Officers .Others Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light &PowerMainConferenceRoom 1200 East First Avenue Anchorage,Alaska 99501(907)279-7671 2286/521/5 Municipal Light &Power e Since 19321200EASTFIRSTAVENUE-ANCHORAGE.ALASKA 99501-1685 TELEPHONE (907)279-7671TonyKnowles. Mayor RECEIVED BY.March 18,1985 ALASKASo Sh "86 MAR 20 PA2:28 Am oN Mr.Afzal H.Khan Alaska Intertie Operating Committee c/o Alaska Power Authority P.O.Box 190869 Anchorage,Alaska 99519-0869 Dear Mr.Khan: As requested in your letter of March 4,1986,Municipal Light and Power has made the following designations for ML&P representation on the Alaska Intertie Operating Committee: Mr.John Cooley,Manager for the Power Management Division of ML&P will become the dsignated representative beginning with the next Operating Committee meeting after the March 19,1986 Operating Committee Meeting. Mr.Mike Massin,Manager for the Engineering Division of ML&P will become the designated alternatie also beginning with the next Operating Committee meeting after the March 19,1986 Operating Committee meeting. The designations will remain in effect until further notice. Sincere 4 Thomas R.Stahr General Manager Municipal Light &Power TRS/slg ce:John Cooley Mike Massin PROVIDE FOR TOMORROW.SAVE ENERGY TODAY. SE.86.47 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE EVALUATION OF GEOMAGNETIC DISTURBANCES ON THE ANCHORAGE-FAIRBANKS TRANSMISSION INTERTIE by Institute of Northern Engineering University of Alaska-Fairbanks Fairbanks,Alaska 99775-1760 March 1986 John D.Aspnes 1.D.Roberts,Director Principal Investigator Institute of Northern Engineering R.P.Merritt Vice Chancellor Co-Investigator University of Alaska-Fairbanks B.David Spell Co-Investigator TABLE OF CONTENTS Page INTRODUCTION...ccc esesccccceececcccceeetesseeeeeeeeeeees beeee 1 PROJECT JUSTIFICATION AND SCOPE..........0seeeseseeeecesseeees 1 DESCRIPTION OF DATA CHANNELS..........020005 bec eeeeeeeeeees we 3 SCHEDULE...esccccecceeececeeeeeeees bee eeeeeeeeeeeeeeeeeeeees 6 REFERENCES.....scceesesees weeeeeeeeeees bee eeeeeeeeeeeeeeneeees 7 BUDGET............beeen eeeeeeceeeeeeneees bee eeeeeseseseeeeee 10 INTRODUCTION This proposal requests continuing support for an on-going project originally funded by the Alaska Power Authority (APA)as part of the Anchorage-Fairbanks Intertie (Alaska intertie)construction cost.The purpose of this project is to obtain operating data for the Alaska intertie related to geomagnetically-induced current (GIC)for a three-year period. Under the terms of the original proposal,APA agreed to pay for costs associated with instrumentation design,development,acquisition, installation and instrumentation software development.Actual data collection and evaluation were not considered to be part of construction,but were to become part of the intertie operating costs. The original contract between the Engineering Experiment Station (now the Institute of Northern Engineering)at the University of Alaska-Fairbanks (UAF)will end on 1 July 1986 and the tasks described above will be completed at that time.This proposal requests support for data collection and analysis for fiscal year (FY)1987 (1 July 1986 to 30 June 1987). We assume that continuation of data collection and analysis through FY 1988 and FY 1989 will be contingent on a favorable project review by the Alaska Intertie Operating Committee near the end of FY 1987.This proposal requests $55,387 for data collection and evaluation during FY 1987. PROJECT JUSTIFICATION AND SCOPE The problem of geomagnetically induced current (GIC)interaction with power systems is a real,present-day operating consideration. Effects of GIC on electric power systems have been presented in several papers (1-17).GIC provides undesirable quasi-de excitation of power transformers with resulting excessive harmonic generation,var flow, voltage fluctuations,variations in power flow because of voltage changes,frequency shifts due to modified power flow,possible system instability due to frequency changes,transformer overheating,incorrect protective relay operation and increased transformer audio noise output. -l- Although GIC effects are qualitatively known,GIC interaction with power systems is a nonlinear problem that is not yet well quantified. Recent notable examples of GIC power system disturbances were in October 1980 and April 1981.These disturbances included a temporary interruption of service in a new 740 km (466 mile)500 kV transmission line between Winnipeg,Manitoba and Minneapolis-St.Paul,Minnesota. James Bay,Canada,experienced two 735 kV transformer failures following a geomagnetic storm in December 1980.Thus,GIC has more than academic interest to electric utilities.GIC may be responsible for significant economic losses. Very little work has been done to determine how GIC affects relay circuits (14).One reported cause of relay misoperations is the interpretation of harmonic currents as zero-sequence or negative-sequence currents.Third harmonics have a zero phase sequence and fifth harmonics a negative phase sequence.Zero-sequence and negative-sequence relays have been observed to operate during geomagnetic storms (15),probably because of harmonic generation produced by GIC excitation of power transformers.Unexplained relay trips have occurred on the existing Healy-Fairbanks transmission line. These were probably caused by GIC,but instrumentation was not in place at the time to verify the cause. The purpose of this project is to obtain operating data for the Anchorage-Fairbanks transmission intertie related to geomagnetically induced current for a three-year period.The data will be analyzed to determine the effect of GIC on transformer real and reactive power requirements,transformer audible noise,relay circuits and intertie reliability.Outages caused by GIC will be identified,as will critical GIC threshold magnitudes relating to unscheduled relay operation. It is probable that geomagnetic storms will adversely affect the proposed intertie.This observation is based on data collected at the Gold Hill substation located at the northern end of the existing Healy-Fairbanks 166km transmission line (11,14)and on reports of GIC outages and equipment failures elsewhere in North America.This project is intended to quantify GIC effects on the Alaska intertie.This will provide a better understanding of GIC-power system interactions,thus determining actual mechanisms for unscheduled service interruptions -2- attributable to geomagnetically induced current.Resulting data analysis is expected to define changes in protective relaying systems, if necessary,and determine specific needs for GIC mitigative measures. An additional project objective is comprehensive documentation of project activities and results.The Alaska Intertie Operating Committee will be kept informed of all aspects of the project and will receive at Teast one formal report per year,as well as the final project report. Results will also be disseminated in appropriate scientific and engineering journals,and by media releases with credit given in each instance to the Alaska Intertie Operating Committee and the Alaska Power Authority for their support. 1. DESCRIPTION OF DATA CHANNELS The following data are proposed to be gathered and analyzed for a 'three-year period. Real power (P watts)and reactive power (Q reactive volt-amperes or vars)required by the three-winding 60-80-100 MVA transformer at the Gold Hill substation near Fairbanks.This will be correlated with geomagnetically induced current (GIC)activity taking into account the existing AC load.This AC load will also include the static var system (SVS)supplied by the delta-connected tertiary windings. Neutral current in the grounding cables for grounded wye 138kV and 69kV windings at the Gold Hill 60-80-100 MVA transformer and for the grounded wye 138kV winding of the generator transformer at Healy.These three neutral current data channels will completely specify quasi-DC (GIC)currents in the Gold Hill power transformers and in the intertie,excluding the Fairbanks side of the Gold Hill transformer.Measuring two of three neutral currents specifies the third (at the intertie's southern end). Current driving a)distance relay,b)overcurrent/directional relays. H-component of earth magnetic field at College,Alaska. Audible noise output of Gold Hill transformer. Earth surface potential (earth current). Primary,secondary and tertiary winding voltages of Gold Hill] transformer. Gold Hill transformer temperature. Line currents to primary,secndary and tertiary windings of Gold Hill transformer. rate (20 channels): Gold Hill transformer Gold Hill transformer Gold Hill transformer Gold Hill transformer Gold Hill transformer Gold Hill transformer Gold Hill transformer by low-pass filter Gold Hill transformer by low-pass filter 'The following data channels will be sampled at approximately 0.5 Hz 138kV winding 3-phase watts 138kV winding 3-phase vars 69kV winding 3-phase watts 69kV winding 3-phase vars 13.8kV winding 3-phase watts 13.8kV winding 3-phase vars 138kV winding grounding current modified 69kV winding grounding current modified Earth-surface potential (earth current) Healy generator transformer 138kV winding grounding current modified by low-pass filter Gold Hill distance relay current Gold Hill overcurrent/directional relay current H-component of earth magnetic field Gold Hill transformer 138kV winding voltage -4- 0)Gold Hill transformer 69kV winding voltage p)Gold Hill transformer 13.8kV winding voltage q)Gold Hill transformer temperature r)Gold Hill transformer 138kV winding line current s)Gold Hill transformer 69kV winding line current t)Gold Hill transformer 13.8kV winding line current The 2 kHz frequency spectra of the following variables will be recorded: a)Overcurrent/directional relay current b)Gold Hill transformer 138kV winding grounding current c)Audible noise from Gold Hill transformer The data specified will allow determination of the effects of geomagnetically induced current on key elements of the operating intertie,namely a power transformer and several relay systems.This is significant to utilities relying on the intertie and to the APA because it will provide information unique to this particular system regarding transformer real and reactive power requirements as a function of GIC. GIC may have a significant effect on transformer service life and will have a definite impact on intertie electrical characteristics.It is important to know how closely and how often relay current and associated current harmonics approach or exceed relay set points during periods of high GIC.It is possible for relays with harmonic restraint to be incorrectly inhibited during geomagnetic storms.Conversely, zero-sequence and negative-sequence relays have operated under similar conditions,probably because of increased third and fifth harmonics. Thus,the ultimate objective of this project is to measure the impact geomagnetic storms have on the Alaska intertie and,having quantified that impact,determine specific GIC mitigation measures or system operating procedures needed to avoid improper relay operations or severe system disturbances. SCHEDULE Timetable Tasks July 1986 Begin data collection and evaluation. 1986 -1989 Continue data collection and evaluation.Provide Alaska Intertie Operating Committee and Alaska Power Authority with annual reports. July 1989 Project termination.Submit final report to Alaska Intertie Operating Committee and Alaska Power Authority. REFERENCES Albertson,V.D.,and J.A.Van Baelen,"Electric and Magnetic Fields at the Earth's Surface due to Auroral Currents",IEEE Transactions on Power Apparatus and Systems,Vol.PAS-89,pp.578-584,April 1970. Aspnes,J.D.,R.P.Merritt and S.-I.Akasofu,"Harmonic generation in transformers related to DC excitation and system loading,”IEEE Transactions on Power Apparatus and Systems,Vol PAS-100,No.2,pp 1845-1851,April 1981. Mohan,N.,J.G.Kappenman and V.D.Albertson,"Harmonics and switching transients in the presence of geomagnetically-induced currents,"IEEE Transactions on Power Apparatus and Systems,Vol. PAS-100,No.2,pp.585-593,February 1981. 'Albertson,V.D.,J.G.Kappenman,N.Mohan and G.A.Skarbakka, "Loadflow studies in the presence of geomagnetical ly-induced currents,"IEEE Transactions on Power Apparatus and Systems,Vol. PAS-100,No.2,pp.594-607,February 1981. Bolduc,L.,and J.Aubin,"Effect of direct currents in power transformers:Part I,A genera]theoretical approach,Part II, Simplified calculation for large power transformers,"Electrical Power Systems Research,Vol.1,pp.291-304,1978. Kappenman,J.G.,V.0.Albertson and N.Mohan,"Current transformer and relay performance in the presence of geomagnetical ly-induced currents,"presented at the IEEE 1980 Summer Power Meeting, Minneapolis,MN,IEEE Paper No.80 SM 646-0. Albertson,V.D.,J.M.Thorson,Jr.,R.E.Clayton and S.C.Tripathy, "Solar-induced-currents in power systems:Cause and effects,"IEEE Transactions on Power Apparatus and Systems,Vol.PAS-92,pp. 471-477,March/April 1973. 8. 10. 11. 12. 13. 14. 15. ACRES Consulting Services,Limited,"Study of the Disruption of Electric Power Systems by Magnetic Storms,"Dept.of Energy,Mines and Resources,Ottawa 3,Ontario,March 1975. Lanzerotti,L.J.,ed.,"Impacts of Ionospheric/Magnetospheric Processes on Terrestrial Science and Technology,"prepared for the Panel on Solar System Plasma Processes of the Study on Space Plasma Physics,Space Science Board,National Academy of Sciences,April 1977. Masson,L.,and J.R.Valotaire,"Investigation of the effects of solar induced DC in H.V.power transformers,"presented at the Canadian Electrical Association Fall Meeting,Calgary,Alberta, October 1974. Akasofu,S.-I.,and R.P.Merritt,"Electric currents in power transmission line induced by auroral activity,"Nature,Vol.279, pp.308-310,24 May 1979. Boerner,W.-M.,,et al.,"Impacts of solar and auroral storms on power line systems,"Proceedings of the 5th International Wroclaw Symposium on Electromagnetic Compatibility,17-19 September 1980. Pirjola,R.,"Induction in power transmission lines during geomagnetic disturbances,"Proceedings of the 5th International Wroclaw Symposium on Electromagnetic Compatibility,17-19 September 1980. Aspnes,J.D.,and S.-I.Akasofu,"Effect of solar induced current on autotransformer tertiary windings,"IEEE Transactions on Power Apparatus and Systems,Vol.PAS-101,No.3,pp.635-637,March 1982. Albertson,V.D.,,J.G.Kappenman and N.Mohan,Discussion of reference 14,IEEE Transactions on Power Apparatus and Systems, Vol.PAS-101,No.3,pp.638,March 1982. 16. 17. Aspnes,J.D.,and R.P.Merritt,"Effect of DC Excitation on Instrument Transformers,"IEEE Transactions on Power Apparatus and Systems,Vol.PAS-102,No.11,November 1983. Akasofu,S.-I.,and J.D.Aspnes,"Auroral Effects on Power Transmission Line Systems,"Nature,Vol.295,No.5845,pp. 136-137,14 January 1982. A.SALARIES BUDGET 1 July 1986 to 30 June 1987 1.Principal Investigator,J.Aspnes4wks@$36.06/hr on>Wwia)ee.°Principal Investigator,R.Merritt3wks@$42.17/hr Principal Investigator,D.Spell4.5 wks @ $27.10/hr Secretary 1 wk @ $12.49/hr Graduate Research Students 1300 hrs @ $10.00/hr BENEFITS 1.16.1%of A.1,A.2 and A.3 2,18.3%of A.4 STAFF BENEFITS - 1.24.6%of A.1,A.2,A.3 and B.1 2.26.6%of A.4 and 8.2 TRAVEL SERVICES 1.Documentation and report preparation 2.Telephone 3.Computer time EQUIPMENT (contingency) OVERHEAD 1.39.2%MTDC (Direct less Equipment) TOTAL -10- SE.86.48 PROPOSAL TO THE ALASKA INTERTIE OPERATING COMMITTEE SYSTEM ANALYSES AND DATA BASE MANAGEMENT by Institute of Northern Engineering University of Alaska-Fairbanks Fairbanks,Alaska 99775-1760 March 1986 John D.Aspnes 1.0.Roberts,Director Principal Investigator Institute of Northern Engineering George Mulligan Co-Investigator Vice Chancellor University of Alaska-Fairbanks INTRODUCTION This proposal requests continuing support for management and update of a data base developed under a previous proposal titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System." We also propose to perform five stability case studies with the modified data base,do a feasibility study to see if a systemwide optimal power flow is cost effective to implement,and perform optimal powerflow studies to minimize cost of generation throughout the Anchorage- Fairbanks interconnected power system.The dynamic stability study proposal was funded by Anchorage Municipal Light and Power (AMLP), Chugach Electric Association,Inc.(CEA),Fairbanks Municipal Utilities System (FMUS)and Golden Valley Electric Association,Inc.(GVEA).The stability study data base,structured to support the Electric Power Research Institute (EPRI)745 transient-midterm stability program, resides with the 745 code in the University of Alaska computer network (UACN).The four utilities named above and the Alaska Power Authority (APA)have access to this data base and stability program.The Alaska Intertie Operating Committee has indicated an interest in having the data base updated and having electric power system stability studies performed using the revised data base. XN PROJECT JUSTIFICATION This proposed project takes advantage of tasks completed under the previous proposal titled "Dynamic Stability Study of the Anchorage- Fairbanks Interconnected Power System."These tasks included assembling a data base for the interconnected Anchorage-Fairbanks electric power systems to be used with the Electric Power Research Institute (EPRI)745 Transient-midterm Stability Program.Five case studies were performed, using the EPRI 745 code.Results are given in the project final report. The resulting data base modeling the Alaska intertie,and the electric power systems it interconnects,resides on the UACN computer network along with a working copy of the EPRI 745 code.The four participating utilities and the APA have access to this data base and EPRI software. -l- Managing and upgrading the data base will help participating utilities obtain the most from their investment in the previous project. The additional tasks proposed should save operating costs. In addition,this project,like the previous one,is an investment in educating future power engineers for the Alaskan utility industry. PROJECT SCOPE Project tasks to be performed include: 1.manage and update the data base currently residing on the UACN computer; 2.perform five stability case studies with the update data base; 3.perform a feasibility study to see if a systemwide optimal powerflow is cost effective to implement;and 4,perform optimal powerflow studies to minimize cost of generation throughout the Anchorage-Fairbanks interconnected power system. PROJECT SCHEDULE Timetable April 1986 -July 1986 July 1986 -December 1986 July 1986 -March 1987 January 1987 -September 1987 Tasks Update and review system data base Perform five stability case studies with the updated data base Perform optimal powerflow feasibility study Perform optimal powerflow studies on the Anchorage-Fairbanks interconnected power systems. BUDGET 1 April 1986 -30 September 1987 SALARIES -WwNee°Principal Investigator,J.Aspnes6wks@$36.06/hr Principal Investigator,G.Mulligan 6 wks @ $28.84/hr Secretary 1 wk @ $12.49/hr Graduate Research Students 1800 hrs @ $10.00/hr LEAVE BENEFITS l. 2. 16.1%of A.1 and A.2 18.3%of A.3 STAFF BENEFITS 1.24.6%of A.1,A.2 and B.1 2.26.6%of A.3 and B.2 TRAVEL 1.One conference trip and travel between Anchorage and Fairbanks SERVICES 1.Documentation and reports 2.Telephone 3.Computer support SUPPLIES 1.Photocopy and expendables 2.Magnetic tape EQUIPMENT 1.Computer programs OVERHEAD 1.39.2%of MTDC (items A through F) TOTAL $8,654 6,923 500 18,000 2,508 92 4,449 157 2,500 800 500 700 700 200 2,000 18 ,300 $66,983 The MINUTES Dispatch Scheduling -Dispatch Training Subcommittee February 12,1986 Dispatch Scheduling -Dispatcher Training Subcommittees held a joint meeting in AMLP's Conference Room at 9:00 AM on February 12, 1986.Those in attendence were: Ray Duncan CEA Ernie Jamison MEA Jim Hall MEA Larry Wolfe APA Stan Sieczkowski AP Admin. John Cooley AMLP Doug Hall AMLP Marvin Riddle GVEA The meeting was called to order by Marvin Riddle,Chairman.Topicsdiscussedwereasfollows: l.Teeland Outage -CEA requested an outage on the Teeland,Pt. McKenzie line to swing towers.This will also kill the 138 KV line from Teeland to Douglas.CEA asked GVEA to supply MEA loadatDouglasapproximately2-3 MW's for 36 hours while they have this section of line out of service.They also requested GVEA keep track of the meter readings and they would like to repay us energy in kind for that supplied to Douglas.GVEA agreed. This outage will occur February 19th at 1000 hes.through February 20th at approximately 1700 hrs.The Intertie will be unavailable during this time.: MEA asked that we have a trial run on feeding Douglas before the outage.The tie is scheduled to zero after midnight on the weekend now,so Saturday,February 15th at.0210 we will de-energize the transmission line between Teeland and Douglas, check voltages at Douglas while radially feeding Douglas from the north;then re-energize the Teeland-Douglas transmission line.Jim Hall stated MEA did not want the regulated bus voltage over 130V on 120V_base.So if the 13&KV voltage was over 150 KV he did not want to re-energize the Douglas distribution load.He wanted to manually open the distribution feeders and run the tap changer down before :restoring the distribution load.Marvin pointed out that AMLP had an RTU in service if MEA and AMLP agreed they could add the additional points to control the distribution sub.This would reduce the outage time at Douglas to a minimum.AMLP-MEA will follow-up on this. Meeting Minutes Page 2 2. 9. The NERC Operating Guide #9 was typed in corrected format with changes and submitted to the Subcommittee.The Subcommittee agreed to present it to the Operating Committee for formal approval. The other contingency discussed was feeding Cantwell radially from the north and south.Marvin said this had been done before but he would submit a write-up on switching required so it could be formally approved and entered in the Operating Manual. After feeding Douglas from the north we will write up a procedure on how to accomplish this and the limitations,then will add it to the Operating Manual. The utilities decided after the Teeland outage,as we were restoring power,we would pick up the MEA-CEA interconnected transmission system from the north =and monitor voltage levels/var flows to determine how far we can energize into the Anchorage system from GVEA to help us in defining operating parameters and limitations when energizing from the north. MEA provided system one-line diagrams showing summer/winter loads by substation.; Ray Duncan says they will need another outage to complete workatTeelandon230KVconversionagaininFebruaryorMarch. G.E.will need the SVS out of service for their "modifications.We do not think this will require a tieline outage but intend to restrict loading levels to approximately 35 MW during this time frame. The utilities present asked for current one-line transmission drawing from GVEA.Marvin agreed to provide this. Training was then opened up for discussion. Marvin stated the Electrical Engineering Dept.at UAF was willing to conduct the seminars.They committed to two sessions,one the week of June 2nd and one the week of June 9th.Course costs would be the same.Dr.Merritt and Dr.Mulligan would conduct the course.The utilities asked that both sessions be advanced.The course outline basically stays the same as last year.A copy is attached with the addition of Static Var System Operation and Interconnected System Operation using tieline as a basis.The other utilities will review the course content to see if they wish to make other changes'and respond before March 1,1986 so these changes can be forwarded to UAF. Meeting Minutes Page 3 The utility committments for course attendance are: AMLP l each session = MEA 2 each session = GVEA 2 each session = Copper Valley -4 one session,3 next Marvin stated he would contact UAF when Marvin {Aare, airman ]&b&NOall comments were back in. Electric Power Dispatcher Training Workshop DESCRIPTION The Dispatcher Training Workshop provides an intensive review of electrical fundamentals and important characteristics of power system components.These topics provide background for a concluding section On power system operation.Each 5-day workshop session is scheduled for 40 hours. SECTION I -FUNDAMENTALS OF ELECTRICITY a.Basic electrical units defined b.Production of electrical energy c.Conductors,insulators,semiconductors d.Ohms Law.amperes,volts watts e.Voltage drop,regulation f.Magnetic fields,electromagnetic induction g.Capacitance,inductance impedance reactance h.Power factor,VARS metering SECTION II -FUNDAMENTALS OF POWER GENERATION Generators -3 phase Prime movers,steam turbine,gas turbines,water turbines Boilers,tubes,superheat,reheater,condensers : Applications,efficiency Diesel generatorsooooOoese«#¢oe@SECTION III -GENERATORS Basic types of rotors Synchronous speed Excitation,saturation Voltage regulation Power system stability Generator connections,neutral MVA,MW,MVARS,KV SECTION IV -TRANSFORMERSanonanaonee*ee8©e@*#@a.Types of cores b.Windings,ideal transformer i c.Turns ratio,voltage ratio,current ratio : d.Practical transformers ' e.Efficiency f.Metering,CT,PT SECTION V -CIRCUIT BREAKERS a.Types,mechanics,oil,air,vacuum b.Ratings,MVA c.Reclosers,sectionalizers ALASKA INTERTIE ---FY87 OPERATING BUDGET ---APRIL 9,1986 ALASKA INTERTIE OPERATING COMMITTEE FY87 OPERATING BUDGET (1) SUBCOMMITTEE Dispatch/Training Dispatch/Scheduling Reliability/Criteria SCADA/Caomm./Metering Handbook/Procedures Machine Rating Reserves/Loadshed (2) NOTES: (1)As revised at Intertie Operating Committee meeting of March 19,1986. PURPOSE Operating Procedures Manual System Analyses &Data Base Management,Evaluation of Geomagnetic Disturbances on the Alaska Intertie Drafting &Supplies for Operating Committee Handbook Drafting Generation Standards Manual --Assembly &Review Review &Coordination of Loadshedding Secretarial Services TOTAL (2)Cost associated with Operating Committee ttAMOUNT 10,000 100,000 3,000 10,000 3,000 12,000 142,000 Alaska Intertie Operating Committee MARCH 19,1986 LA MASE Jl uP 263-§2U2 Harry BECK APA 2b)-7262 Aye 4e WA £WYAW APA PCEf-Fay & bdo C.WernhleOh CEN $6 Y-0603 'Key LTD),nea x CELA 54H -0O187 bah foe eve ti fae je | ia Ne TRACE ALA Go(-7Ab To His ASHES UAF 474 60% TIM HALL MERK 245-3231 Tohn_-Combs mcpP 63 S¥SO Eel Pt)evres LL A 2b /-72/4 Vases krvote Gvef Aca -WO¢Lest Cole Rus YSo-/00DdawWetitn,AEC ET |275-9167L.dle ec.MLEP Llo3 -S243 Dawe Eberle APA IV. VI. VIT. VIII. IX. ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,APRIL 23,1986 BEGIN at 9:00 A.M. Adoption of prior meeting minutes-ere mvc',(olp unmom.Poll prove Ath,fm be.OeP aw 5 Approval/modification of agenda -UF grogese! Committee correspondence and reports A. Dispatch/Scheduling Subcommittee .B. Intertie Status Update (A.P.A.)Cemmac:./oV:peg |C.Proposed pperaring Committee Manuals Updating 24.4.4 d,UAE Yrahd be sée/>(resVisitorcommeftsrovaedtoitems on agenda Old Business New Business SessA.Recess and work ; B.Dispatcher/Scheduling C.University of Alaska -Fairbanks presentation /034 -nom D.Intertie Operating Committee Manuals consolidation E. Intertie Budget FY87 F.OQthers Formal.Operating Committee action/recommendation Subcommittee assignments Adjournment Adjourn by 3:00 p.m, Meeting location:Fairbanks Municipal Utilities System Board Room 645 5th Avenue Fairbanks,Alaska 99707 (907)456-1000 3928/591(1) Vv Record CopyheatcrtFile#QWE PRO 3-4 ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,JANUARY 15,1986 (AT CHUGACH ELECTRIC ASSOCIATION) Attendance: Harry Beck Alaska Power Authority Ed Morris Alaska Power Authority Howard Thacke Alaska Power Authority John S.Cooley Anchorage Municipal Light and Power Larry Hembree Anchorage Municipal Light and Power Mike Massin Anchorage Municipal Light and Power Ray L.Duncan Chugach Electric Association Bradley Evans Chugach Electric Association John C.Marshall Chugach Electric Association Larry Colp Fairbanks Municipal Utilities System Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Dave Barden Homer Electric Association,Inc. James Hall Matanuska Electric Association The meeting was called to order by Chairman Mike Massin at 9:10 a.m.in the Electrical Engineering Department Conference Room at Chugach Elec- tric Association. Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unanimously. Mike Massin motioned for the agenda to be adopted as written and John Marshall seconded the motion.The motion was approved unanimously. Under Committee's Correspondence and Reports,Mike Massin noted that the Operating Committee had sent a letter to Dave Eberle of the Alaska Power Authority concerning unresolved technical problems on the Alaska Inter- tie Project,the resolution of these problems and how it may impact the signatory process of the Alaska Intertie Agreement.Mike Massin report- ed that the Operating Committee had sent a letter to Rudy Etheridge of the Alaska Power Authority urging the designation of an additionalpersontoberesponsibleforadministeringtheprovisionsoftheAlaska Intertie Agreement.Mike Massin also reported that the Operating Committee had sent a letter to Dan Rice of Engineering Design Associates expressing the thanks and appreciation for his efforts on helping theOperatingCommitteerealizethesuccessfulstart-up of the Alaska Intertie.Finally,Mike Massin noted that a reply to the OperatingCommittee's letter to Dave Eberle of the Alaska Power Authority had been received from Dave Eberle.In his reply,Mr.Eberle responds to the outstanding problems identified in the original letter and discusses the Alaska Power Authority's plan for solving them. 2756/538 Bob Orr reported on the SCADA/Metering/Communications Subcommittee meeting held on January 14,1986 at 9:00 a.m.in the Engineering Confer- ence Room at Chugach Electric Association.Bob Orr furnished the Operating Committee with a set of minutes,see attached.He noted that the subcommittee had revised and formalized the "Testing Standards for Alaska Intertie Revenue Metering"(also attached)and were now submit- ting it to the Operating Committee for adoption. Marvin Riddle made a presentation on the Dispatch/Scheduling Subcommit- tee meeting conducted on January 14,1986 at 1:00 p.m.in the Engineer- ing Conference Room at Chugach Electric Association.Minutes of the meeting were not available.He reported that the subcommittee was exploring the contingencies/actions that should be taken following catastrophic disturbance to or failure of the interconnected Anchorage- Fairbanks system.He then stated that this topic will continue to be analyzed in subsequent subcommittee meetings. Turning to Intertie Status Update,Harry Beck reported on the status of the preparation and completion of the SCADA,Maintenance and Trans- mission Service agreements for the Alaska Intertie.He noted that the SCADA agreement had been sent to Chugach Electric Association and Municipal Light and Power for review and comment.He further noted that comments had only been received from Chugach Electric Association. Mike Massin stated that Municipal Light and Power had sent reviewcommentstotheAlaskaPowerAuthoritysometwo(2)months ago when they had last received the SCADA agreement.Harry Beck noted that he would inform Afzal Khan of the Alaska Power Authority of this situation upon Mr.Khan's return to Anchorage.It was requested that review copies of the Maintenance and Transmission Service agreements be made available to all Operating Committee members. Ed Morris then stated that the Operating Agreement had been signed by all participants.A question was asked relating to what this year's budget for operating and maintenance.Harry Beck noted that the final plan and budget for operation and maintenance of the Intertie for theinterimperiod(i.e.,onset of commercial operation to end of currentfiscalyear)had not been developed.It was questioned if the Intertie could be considered "in commercial operation"if the plan and budget were not approved and in-place.Ed Morris stated that commercial operation was not prohibited if the rates were not established prior to the onset of commercial operation.Marvin Riddle stated that trans- mission costs have to be established before you can dispatch power overtheIntertie.Mike Massin then stated that (1)an operating and mainte-nance budget has to be established,(2)the Transmission Service Agree-ment has to be in-place and,(3)Chugach Electric Association's costs for transmission service has to be established,and that these remain outstanding tasks to be completed. Harry Beck reported that Afzal Khan and Dave Eberle were in Philadelphia this week to meet with officials of General Electric.He stated that the purpose of the meeting was to examine outstanding problems 2756/538 associated with the static var systems (SVS).It was reported that additional work was still required at Teeland substation.This work included the addition of "soft-start"circuitry to the logic of the SVS, corrections to the S&C modules and corrections to the metering equipment.Bob Orr stressed that it was important that someone coordinate this work effort.Ed Morris then reported that the responsibility for Intertie operations and maintenance had shifted from Rudy Etheridge to himself.Ed Morris further stated that the individual at the Alaska Power Authority that will ultimately be charged with the specific responsibility for the Intertie will not be designated until after the completion of the negotiations with the 4 Dam Pool. Mike Massin then reported that Afzal Khan and himself were to have met last month on the updating of the proposed Operating Committee Manuals. He indicated that this meeting did not take place but would in the coming month.He further stated that the Operating Committee needed each organization to identify who in that organization would be the record holder.Mike Massin then indicated that new manuals needed to be made. There were no visitors present at the meeting. There was no Old Business to consider. Under New Business,the Operating Committee went into work session at 10:10 a.m. Mike Massin reported that Dr.John Aspnes,Head of the Electrical Engineering Department,University of Alaska,Fairbanks had postponed the presentation of their report,"Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System."Harry Beck reportedthattheUniversityhadidentifiedaproblemwiththerelayingmodule of the source code resulting in errors in the solution of the cases.He stated that the University had located the problem and were in theprocessoftestingthemodulepriortotherunningofthecasesand thereissuanceofthestudy.Larry Hembree discussed problems that he felt were present in the report involving reverse power relaying. John Cooley identified errors in the data base associated with the scheduling of generation.It was recommended by the Operating Committee that the University be requested to incorporate changes to the system data base prior to the running of the cases for the revised study. These changes would be furnished by the individual utility who would ensure that the information provided the University was complete and accurate.The Secretary of the Operating Committee was directed toconveythisrequesttotheUniversity. Turning to SCADA/Metering/Communications subcommittee,Bob Orr suggested that the Operating Committee formally adopt the "Test Standards ForAlaskaIntertieRevenueMetering."He further suggested that theOperatingCommitteeputthe"Intertie Metering Requirements"as anattachmenttothestandardswhentheyareplacedintheOperating 2756/538 Manual.Bob Orr then requested that the Operating Committee consider what additional tasks should be assigned to the Subcommittee.It was the concensus of the Operating Committee that no reply had been received from Mr.Mike Ridge of the Alaska Division of Telecommunications(DIVCOM)regarding the request for an additional voice channel for communications between Golden Valley Electric Association and Anchorage Municipal Light and Power.It was suggested that Mr.Afzal Khan be requested to monitor this situation. Moving on to Dispatch/Scheduling Subcommittee,Marvin Riddle stated that he would contact the University of Alaska,Fairbanks,and check on the courses and schedules available for this year's dispatcher training workshops.Interest was expressed by the Operating Committee in the computer simulator at Golden Valley Electric Association..Bob Orr suggested that the Dispatch/Scheduling and Dispatcher/Training Subcom- mittees conduct a joint meeting during the next month. Under Operating Committee Manuals consolidation,Mike Massin reported that the new manual will be put together soon and handed out to each of the designated representatives of the Operating Committee.Ed Morris indicated that he would provide copies of the signed Operating Agreement for inclusion in the manuals.. Under Others,it was noted that the Intertie Operating Committee is tasked with annually calculating the MITCR and that the Committee should be aware of this fact.It was noted that the annual election of offi- cers will be conducted at the next meeting in March.Mike Massin suggested that the members think about potential nominees prior to the election.The Secretary was instructed to send a letter from the Operating Committee to each of the General Managers requesting that they designate their official representative and alternate to the Operating Committee. Ed Morris was then asked to present a report on the status of the remaining deficiencies associated with the substations and their equip- ment.He then addressed Bob Orr's letter to Dave Eberle dated November 12,1985 (see attached).Replying to the section of Bob Orr's letter entitled,"Corrective Actions",Ed Morris indicated that item 1 had been resolved and that item 2 was still being examined by GeneralElectric.Bob Orr concurred that the harmonic problem (i.e.,item 1) had been solved and that he had received a notice from General Electric confirming that fact.Ed Morris then addressed that section of the letter listed the outstanding deficiencies still existing at the sub- stations.His response to each item is listed below with the numbering of the items consistent with that used in Bob Orr's letter: 2756/538 Item #RESPONSE 1/2 Did not indicate current status or action to be taken 3/4/22 Being discussed with General Electric 5/6/7 These will be examined after the SVS operational problems are resolved 8/15/16/21 These will not be corrected by the Power Authority 9 Bearing sent to General Electric for analysis of failure -Further action contingent upon analysis 10 Did not indicate current status or action to be taken 13 Gilbert/Commonwealth analyzing their design -Further action contingent upon analysis 14 Will require further study 15 Do not believe this to be a problem -may be eliminated when SVS bus modifications are made 17 Gilbert/Commonwealth analyzing their design -Further action contingent upon analysis 18 Being discussed with General Electric 19/20 -Being discussed with General Electric 23 Did not indicate current status or action to be taken Bob Orr then elaborated on the problems with the S&C modules by first describing the principle of operation,their alarms and shutdowns,and finally the need for calibration of these units.John Marshall then described that the SVA over/under-voltage relay at Teeland was not set properly and that this was evident from the recent failure of the attempt to energize and start the Teeland SVS from the Northern Area. Bob Orr then noted that he had never seen a proper acceptance test procedure for any of the substation systems or equipment. Under formal Operating Committee action/recommendation,Bob Orr motioned that the Operating Committee adopt the "Test Standards for AlaskaIntertieRevenueMetering."John Marshall seconded the motion.The motion was adopted unanimously. Bob Orr then moved that the Intertie Operating Committee adopt a bi- monthly meeting schedule with the next meeting of the Operating Commit- tee scheduled for March 12,1986.Mike Massin seconded the motion.The motion was adopted unanimously. 2756/538 Chairman Mike Massin then directed the Secretary to report to John Marshall,Chairman of the Relaying Subcommittee,after General Electric has decided what action to take regarding the settings for the SVS over/under-voltage relays.John Marshall will then decide,based on the information that he receives,whether to call a meeting of the Relaying Subcommittee. Turning to Subcommittee assignments,Chairman Mike Massin directed the DISPATCH/SCHEDULING and DISPATCHER/TRAINING SUBCOMMITTEES TO MEET JOINTLY ON WEDNESDAY,FEBRUARY 12,1986 AT 9:00 A.M.IN THE MAIN CONFER- ENCE ROOM AT MUNICIPAL LIGHT AND POWER for the purposes of (1)examiningsystemcatastropherestorationproceduresand.(2)discussing the courses and schedules for the University of Alaska dispatcher training workshop. The Operating Committee then proceeded to set the agenda for the next full meeting of the Operating Committee. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,MARCH 12,1986 AT 9:00 A.M.IN THE MAIN CONFERENCE ROOM AT MUNICIPAL LIGHT AND POWER AT 1200 E.FIRST AVENUE, ANCHORAGE,ALASKA. Larry Colp then motioned for the meeting to adjourn.Harry Beck second- ed the motion.The Operating Committee then unanimously adopted the motion to adjourn at 1:40 p.m. Respectfully submitted, Opac HM.khau- Afzal H.Khan,Secretary Alaska Intertie Operating Committee 2756/538 Attachments: 1. 2. March meeting agenda Minutes from January 14,1986 SCADA/METERING/COMMUNICATIONS Subcom- mittee Meeting Test Standards For Alaska Intertie Revenue Metering Golden Valley Electric Association letter to Alaska Power Authority dated November 12,1985 Alaska Intertie Operating Committee letter to Mr.Rudy Etheridge, Alaska Power Authority dated December 4,1985 Alaska Intertie Operating Committee letter to Mr.Dave Eberle, Alaska Power Authority dated December 4,1985 Alaska Intertie Operating Committee letter to Engineering Design Associates dated December 4,1985 Alaska Power Authority letter to Alaska Intertie Operating Commit- tee dated January 10,1985 2756/538 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,MARCH 12,1986 BEGIN at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda II.Committee correspondence and reports A. Dispatcher/Training B. Dispatch/Scheduling SubcommitteeC.Intertie Status Update (A.P.A.) D.Proposed Operating Committee Manuals Updating IV.Visitor comments related to items on agenda V.Old Business VI.New Business Recess and work station Dispatcher/Training Dispatch/Scheduling Intertie Operating Committee Manuals consolidation Election of Officers OthersAMOOQBDDYy VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light &Power Main Conference Room 1200 East First Avenue Anchorage,Alaska 99501 (907)279-7671 2286/521/5 MINUTES SCADA/Metering Communications Subcommittee Date:1-14-86 Time:9:00 A.M. Place:CEA Engineering Conference Room Persons in Attendence Robert Orr GVEA John Cooley AML&P Vance Cordell CEA Doug Hall AML&P Ray Duncan CEA Marvin Riddle GVEA Larry Colp FMUS Glenn Davis CEA Jim Hall MEA Data Link Update No activity since last update.GVEA and AML&P are using scratch pad manual entry for schedules and selective southern system points. GVEA is sending AML&P a few specific points via packet lists from real time data base. One-line information for lists still needs to be exchanged between GVEA and AML&P for development of the real time data packets. CEA is moving along on the agreement with APA but no agreement is signed. Testing Standards for Alaska Intertie Revenue Metering The committee revised the testing Standards (attached)and formalized it for submittal to the full Operating Committee foradoption. JEANG,(Es"Robert Orr Subcommittee Chairman TEST STANDARDS FOR ALASKA INTERTIE REVENUE METERING Testing Interval Test on annual basis in month of June,starting June 1986.Any unscheduled meter testing shall be approved by the Operating Committee. Sealing No special sealing required.(62,4 $°-/PPO ng cen rs Advance Notice for Testing The utility responsible for test will give advance notice to all Participants and the Operating Committee at least 30 days in advance of the test. Calibration The test-standard for meter testing shall be calibrated and shall be traceable to Bureau of Standards.It must be capable of 13% accuracy.The meter test-standard to be used for testing will have to have been calibrated in the last five years. Watt hour and VAR hour metering shall be within the accuracy specified in the current Intertie metering requirements document.A test report showing as-found and as-left values and results is to be recorded and submitted to the participants and the SCADA/Metering Subcommittee.The test report shall also show test-standard used, personnel present,date test-standard was certified and date of revenue meter test.Sticker shall be affixed to the face of the meter showing date tested,person testing,and persons witnessing tests. SCADA/Metering Subcommittee shall review all meter test reports for approval and action as necessary. CT/PT Accuracy -Ratio Testing No CT/PT accuracy testing is anticipated unless requested by SCADA/Metering Subcommittee and approved by Operating Committee. Remote Versus Local Accuracy Field check pulse accumulators at least annually during meter calibration and include in metering test report. Monthly removal of demand bubble memory modules -The monthly demand modules shall be removed monthly and translated into a standard format.These must be removed after the end of the month but within three days after the end of the month. Date Revision Page l Standards for Alaska Intertie Revenue Metering Page 2 This information will be the basis for the monthly review by the participants and annual review by the Operating Committee.The review shall consist of the following comparisons: a)Instantaneous analog field versus SCADA _remote reading, annually. b)Field pulse counter versus SCADA pulse counter,annually. c)Monthly field register versus field bubble memory MWH for same time period. d)Monthly field bubble memory versus SCADA accumulated MWH for Same time period. Meters To Be Tested Those meters identified per the Intertie metering requirements approved by the Operating Committee. Responsibilities for Above Categories The utility responsible for maintenance is responsible for testing and gathering of the monthly data and submission to the area controller.The area controller is responsible to summarize the monthly data within their control areas and format it to present to the SCADA/Metering Subcommittee. Date Revision Page 2 1) 2) 8-10-83 INTERTIE METERING REQUIREMENTS REVENUE METERING REQUIREMENTS All facilities tapped off the intertie between Healy and Teeland shall have adequate metering which is compatible with,and telemetered to the appropriate Control Area Control Center.The metering requirements are as set forth in FigurelorFigure2dependingonthefacility.If the power flow capabilities are only one direction Figure 2 applies.If the power flow capabilities are bi-directional Figure 1 applies. Any participant using intertie rights must have adequate metering which is compatible with,and telemetered to the appropriate Control Area Control Center.This metering must be located at the tie point of the participant to the grid. The metering requirements are as set forth in Figure l. OPERATING METERING REQUIREMENTS In addition to the revenue metering requirements the following additional metering is required or recommended as identified for operation of the interconnected system: A)Require local and remote buss voltage meter. Recommend local and remote 3 phase voltage and current metering. B)Require local and remote syncronizing capabilities on the tie breakers.The local syncronizing panel shall consist of the following as a minimum:analog voltage meter and syncronizing light indicators for each side ofthebreaker;360°-synce-scope.The sync-scope selector switch shall supervise breaker local "close"commands. All local and remote breaker "close”commands shall be supervised by a syncro-check relay. C)Recommend local In/Out Watt strip chart recorder with zero watt center scale. All remote capabilities are to be compatible with,and tele- metered to the appropriate Control Area Control Center. TYPICAL REVENUE METERING FOR INTERCONNECTED OPERATION INTERCONNECT.PT METERINGANCLASSREQUIRED YC WH VARH (0.3 Accuracy) =mn mM ad uu - 2 CEE OOM OO®7,CT METERING T T=|W cuass REO'D°(0.3 Accuracy) Vv RTU 1 ! DEMAND RECORDER L ---- >DATA LINK TOA CONTROL CENTIJALLTRANOUCERSTOHAVE.25'ACCURACY MINIMUM ALL METERS TO HAVE 1%ACCURACY 3)ALL METERS TO HAVE DETENTSa TYPICAL REVENUE METERING FOR TAPS OFF THE INTERTIE POWER FLOW DISTRIBUTION Ss >loneBUSeoyo CT !7 {|j PT METERING.METERING CLASS REQUIRED RECUIRED (0.3 Accuracy) W1(0,3 Accur RCY )(1.2 Accuracy or&(=)Douglas Tap ishandWHVARH- :|o--_f\__--9 ,YY RTU i Y VY . Lo_>DATA LINK TO AREADEMANDCONTROLCENTERRECORDER 1)ALL TRANSOUCERS TO HAVE .25%ZACCURACY MINIMUM 2)ALL METERS TO HAVE 1%ACCURACY 3)WATTHCUR AND VARHQUR DEMANO LOCALLY RECORDED 4)ALL METERS TO HAVE DETENTS > TEST STANDARDS FOR ALASKA INTERTIE REVENUE METERING Testing Interval Test on annual basis in month of June,starting June 1986.Any unscheduled meter testing shall be approved by the Operating Committee. Sealing No special sealing required. Advance Notice for Testing The utility responsible for test will give advance notice to all participants and the Operating Committee at least 30 days in advance of the test. Calibration The test-standard for meter testing shall be calibrated and shall be traceable to Bureau of Standards.It must be capable of 1% accuracy.The meter test-standard to be used for testing will have to have been calibrated in the last five years. Watt hour and VAR hour metering shall be within the accuracy specified in the current Intertie metering requirements document.A test report showing as-found and as-left values and results is to be recorded and submitted to the participants and the SCADA/Metering Subcommittee.The test report shall also show test-standard used, personnel present,date test-standard was certified and date of revenue meter test.Sticker shall be affixed to the face of the meter showing date tested,person testing,and persons witnessing tests. SCADA/Metering Subcommittee shall review all meter test reports for approval and action as necessary. CT/PT Accuracy -Ratio Testing No CT/PT accuracy testing is anticipated unless requested by SCADA/Metering Subcommittee and approved by Operating Committee. Remote Versus Local Accuracy Field check pulse accumulators at least annually during meter calibration and include in metering test report. Monthly removal of demand bubble memory modules -The monthly demand modules shall be removed monthly and translated into a standard format.These must be removed after the end of the month but within three days after the end of the month. Date Revision Page l Standards for Alaska Intertie Revenue Metering Page 2 This information will be the basis for the monthly review by the participants and annual review by the Operating Committee.The review shall consist of the following comparisons: a)Instantaneous analog field versus SCADA remote reading, annually. b)Field pulse counter versus SCADA pulse counter,annually. c)Monthly field register versus field bubble memory MWH for same time period. d)|Monthly field bubble memory versus SCADA accumulated MWH for same time period. Meters To Be Tested Those meters identified per the Intertie metering requirements approved by the Operating Committee. Responsibilities for Above Categories The utility responsible for maintenance is responsible for testing and gathering of the monthly data and submission to the area controller.The area controller is responsible to summarize the monthly data within their control areas and format it to present to the SCADA/Metering Subcommittee. Date Revision Page 2 GOLIDEN VALLEY ELECTRIC ASSOCIATION INC.Sox 1249,Fairbanks,Alaska S9707 Phone S07-4252-115 November 12,1985 Mr.Dave Eberle Alaska Power Authority 334 West Fifth Avenue Anchorage,Alaska .99501 SUBJECT:SVS Operational Characteristics Dear Dave: On April 5,1985 I sent you a letter outlining GVEA's concerns with the startup characteristics of the HLS and GHS SVS units.In summary there were three major concerns. 1)The harmonic generation problem at Healy during HLS SVS Startup. 2)Voltage levels during SVS startup at Healy. 3)Voltage levels during SVS startup at Gold Hill. To date,the following corrective measures have been taken.I will list them by the same number as listed above. Corrective Actions 1)During September and October 1985 G.E.made modifications to the HLS &GHS SVS starting control circuits which accomplished the following results: a.Reduced the harmonics during SVS starting to a level which the HLS SVS can be started with Healy Plant on line.G.E. subsequently withdrew their restriction per letter dated October 22,1985.GVEA has successfully started the HLS SVS with Healy Plant on line and islanded from the Anchorage grid. b.The energy impact and subsequent "bump"to the GVEA system during'SVS starting has been substantially reduced by the "new"starting logic. :2)The voltage levels during HLS SVS startup have been changed by the "new"starting logic but have not been corrected.The voltage excersions are still excessive and beyond the normally - o (° GOLOEN VALLEY ELECTR BSOCIATION INC. November 12,1985 Page 2 acceptable levels of .9pu to 1.10pu.The following information was extracted from the G.E.HLS SVS up-sequence ocillograph taken at 1:00 p.m.on September 21,1985.This up-sequence is with the "new"starting logic. --6 cycles from start signal for thyristor minimum current to be established.There was no apparent voltage dip due to the thyristors firing at minimum current.; --87 cycles (1.45 seconds)from start signal to prestrike of capacitor switch.Upon prestrike the following occurred. a.The 138KV bus voltage increased by 37%.It took 5 cycles for the SVS to bring the voltage back to 100%. b.The SVS 12KV bus voltage increased by 58%.It took 5 cycles for the SVS to bring the voltage back to 100%. The duration of this voltage excursion is acceptable but the magnitude is not!This 1.37pu voltage is well beyond the l.lpu value. --190 cycles (3.17 seconds)from start signal to close of the capacitor switch as monitored by its 52A contacts.This just shows how slow this switch really is! All in all,the "new"SVS starting logic has improved the starting performance considerably.This starting logic should be retained but modified for step starting by use of two capacitor switches.Judicious selection of the amount of capacitors switched in on each step may reduce the voltage swing magnitude to an acceptable level. 3)All comments made for the HLS SVS in Item No.2 above apply to the GHS SVS.I do not have copies of the GHS SVS up-sequence ocilligraphs to analyze in detail.Although,the results are expected to be nearly the same or slightly worse. This concludes my comments relative to the SVS Starting characteristics. The HLP and GHS SVS sytems have several other problems.Most of these problems have been verbally given to G.E.,Morrison-Knutson and APA.Some'have been addressed in other correspondence as well. The intent of listing the problems here is to develop a comprehensive list of all problems to-date,which have not been corrected. ey GOLDEN VALLEY ELECTRI November 12, sSSOCIATION INC. 1985 Page 3 The towards anyone Magnitude that Problems which responsibility for corrective action is not implied or directed other than APA. current "open"item list: Problem 1)GHS &HLS SVS MVAR remote 2) 3) 4) 5) 6) 7) metering is not reading properly. GHS &HLS SVS MW/MWH remote metering needs to be made operational.This is needed to monitor losses and account for this energy. HLS SVS remote voltage set points need to be changed from the existing 131KV-1l45KV to 133KV-147KV based on system operating experience. HLS SVS doesn't control any- where close to its set point. Set point of 145KV produces a regulated buss voltage of 140.0KV.That's a difference of 4KV. HLS &GHS SVS control building has ice buildup problems on eves over buss feed throughs. HLS &GHS SVS buss in switch yard is too low.Snow covers buss which hides buss and can cause fault if snow becomes contaminated.Also safety hazard. HLS &GHS SVS buss feedthrough into building are not through one window causing excessive heating and losses. have been corrected are not listed. problems are of a sufficient they should be corrected. Following is the Action Required Install test switch,original 2-1/2 element transducer in place of current 2 element transducer.Phase angle connect properly and calibrate. Install test switch,MW/MWH transducer,SCADA analog point with accumulator,phase angle and connect properly and calibrate. Make appropriate field changes and SCADA data base changes. Make field modifications as necessary. Make building and buss feed through modifications as required. Raise buss. Relocate and redesign buss feedthroughs. GOLOEN VALLEY ELECTRI <SSOCIATION INC. November 12,1985 Page 4 Problem 8)HLS &GHS SVS.Install SVS 9) 10) 11) 12) 13) 14) 15) building door alarms and switchyard gate alarms. SCADA. Tie to HLS SVS cooling fan bearings failed. HLS &GHS SVS spare parts need to be completely inventoried to determine if all required Spares with proper P/N are Present at each location.HLS spare fan bearings were wrong P/N. HLS &GHS SVS thyristor cells fail during hard shutdowns. HLS &GHS unbalance SVS capacitor neutral circuits not working properly.Unbalance is currently at a magnitude which loss of the first capacitor will cause SVS trip.Modules have been unsuccessfully added to correct this problem. HLS &GHS SVS cooling system outside air intake is building up with frost and ice thereby plugging the intake. HLS &GHS SVS critical power for the stabilizing transformer. 20A 240V is being fed from the station service which is interruptable causing SVS shut- down. HLS &GHS SVS need additional fence in control building to block off back side of thycistor compartment and ovechead bus.This is cuccently a safety hazard. Action Required GVEA to install and bill APA. Provide report on cause of failures. Inventory. Investigate and correct. Devise and implement circuits which will work. Investigate and modify to correct. Move this critical power to a new and secure phase to phase PT specifically for this pucpose or install a UPS for this circuit. Design and install fence. GOLDEN VALLEY ELECTRIt.ASSOCIATION INC. November 12,1985 Page 5 16) 17) 18) 19) 20) 21) 22) 23) 24) C Problem HLS SVS.Install gates in outer perimeter fence at the SVS control building doors. HLS &GHS.Re-evaluate SVS building heat.Don't believe heat is adequate with SVS off at -60 degrees F. HLS &GHS SVS.Install an analog temp.sensor in cooling plenum to provide SCADA alarm prior to trip temperature of 32 degrees F. HLS SVS cooling system blowers run only on fast speed and cannot be changed to low speed. HLS SVS failed to transfer Properly to backup cooling when primary cooling fan bearings failed. GHS needs shelves for spare parts installed in control building entry. GHS SVS doesn't control any- where close to its set point. Set point of 71.5KV regulates buss at voltage of 70.3KV. HLS &GHS SVS.Need full set of GE drawings and schematics including Card Level Back- sheets for trouble-shooting problems. HLS &GHS SVS appear to be _undersized.During recent GVEA testing,HLS 138KV bus sagged to 131KV,GHS 69KV bus sagged to 63KV and all three (Healy,Gold Hill and Teeland) SVS outputs were at maximum capacitive output and not regulating,Healy Plant was putting out over 20MVAR and Action Required Install. Evaluate. Design and install. Investigate. Investigate. Design and install. Make field modifications as necessary. Please provide. Investigate and provide required capacity. i.mn "7 GOLDEN VALLEY ELECTRi.ASSOCIATION INC. November 12,1985 Page 6 Problem Action Required Anchorage-Fairbanks Intertie line loading was approaching 70MW. The SVS units should be sized to maintain 1.0pu voltage during this energy transfer on the Intertie. 25)HLS &GHS SVS.Need comprehen-Please provide final Sive field acceptance and acceptance test plan to performance test for the SVS GVEA as soon as possible. systems.This needs to be formally witnessed by APA and the affected utility.Test documents need to be made available for review at least3weekspriortoactualtest. System configuration for tests needs to be described in detail. Items 9,10,13,14,18,and 24 are new problems added.Some of these'could cause serious operational restrictions and/or affect system reliability significantly. I hope these comments are taken in the positive context intended--that GVEA's only interest is to help in assuring the SVS systems operate and perform as they were intended,consistent with accepted utility practices.I am sure most,if not all,of these items have been brought to your attention by your commissioning Startup representatives.I will be happy to provide further explanation on any item upon your request. Ataf,LeanR.Orr Operations Supt. cc:Lee Warnock,MK Afzal H.Khan,APA John Huber,GVEA Mike Kelly,GVEA Howard Thacke,APA Marvin Riddle,GVEA Rudy Etherige,APA Alaska intertie Operating Committee December 4,1985 Mr.Rudy Etheridge Associate Executive Director of Projects Alaska Power Authority 334 W.5th Avenue Anchorage,AK 99501 Dear Mr.Etheridge: Now that the Alaska Intertie has begun operating on an interim basis and very shortly the utilities and the Alaska Power Authority will be entering into a contract to utilize the line on a long term basis,it is essential that Alaska Power Authority give immediate attention to the designation of a person within theAlaskaPowerAuthoritywhowillberesponsibleforcarryingout and coordinating the duties set forth in the Alaska Contract Agreement. In particular the Committee is concerned about the Alaska Intertie Operating budget process and the gathering and disseminating of information on such things as operating costs and the Intertie usage.This is a very important part of the process required to make this project move ahead successfully. I would urge you to consider not placing this responsibility directly with the Power Authority Representative on the Operating Committee as this person appears to have his hands full already. Thank you in advance for considering my request.Should you have any questions regarding my request,please feel free to contact me at 263-5222. Sincerely, VeeMikeMassin,Chairman Alaska Intertie Operating Committee MEM/clc Alaska Intertie Operating Committee December 4,1985 Mr.Dave Eberle, Project Manager/Bradley ; and Small Hydro _ Alaska Power Authority 334 W.5th Avenue Anchorage,AK 99501 Dear Mr.Eberle: At the last meeting of the Alaska Intertie Operating Committee which was held in Fairbanks on November 13,1985 all of the uti- lity participants expressed frustrations about the progress of the efforts to resolve several loose ends on the Alaska Intertie Project.These include such things as raising the 13.8KV bus at Gold Hill and Healy,correcting the inductive heating problem on the 13.8V bus which exits the control building at Healy,as well as many other items which have been repeatedly raised by the utilities directly or at the Operating Committee meetings. Mr.A.H.Khan has been doing a commendable job in representing the Alaska Power Authority on the Operating Committee,but I sense that he alone cannot give the Operating Committee full assurance that these areas of concern are going to be addressed in the near future. The Operating Committee is keenly aware that initial use and even- tual commercial operation of Alaska Intertie should not be placed in jeopardy by the concerns of the Operating Committee and the Committee certainly does not want to hold up the signing of the long-term contract agreement.We are concerned,however,that once the contracts are signed that some of these areas of concern may stay on the back burner or that the utility participants may be left with the financial liability of following through with the punch list items. It might be helpful if you came to the next Operating Committee meeting which will be held at the Chugach Electric Association Training Room on Wednesday,January 8,1986 at 9:00 A.M.to pro- vide the Operating Committee members with any additional infor- mation which might alleviate some of the Committee concerns. I would welcome the opportunity to discuss this matter further by telephone at your convenience.I can be reached at 263-5222. Sincerely, VE'MikesMassin,wChairman. Alaska Intertie Operating Committee MEM/clcec Alaska Intertie Operating Committee December 4,1985 Mr.Dan Rice,President esEngineeringDesignAssociates 2 Plaza Southwest 6900 S.W.Haines Road Tigard,Oregon 97223 Dear ne, On behalf of the Alaska Intertie Operating Committee I'd like to take this opportunity to thank you for your efforts over the past three years in helping the Operating Committee and the utilities as well as the Alaska Power Authority who are represented on the Committee in realizing the successful start-up of the new Alaska Intertie. Through your efforts the Operating Committee was formed well in advance of the initial start-up of this project and as a result of your guidance and hard work the Operating Committee has been able to pull together the many important issues and actions required for this project to get off to a good start.Without your dedica- tion,the task would have been a very difficult one to say the least. An equally commendable effort which relates to your help with the Alaska Operating Intertie Committee was your recognition of the need for the various utilities personnel to get to know and work with each other on a close personal basis.As a result of the Alaska Intertie Operating Committee and subcommittee meetings,the various utilities began working closely for the very first time. You can and should be very proud of the fact that you were the driving force in making one of the most important power projects in Alaska come to life.Thank you! Sincerely, M ChairmanikeMassin, Alaska Intertie Operating Committee MEM/cle \ Alaska Power Authority State ot Alaska January 10,1986 Mr.Mike Massin,Chairman Alaska Intertie Operating Committee c/o Anchorage Municipal Light &Power 1200 East Ist Avenue Anchorage,Alaska 99501 SUBJECT:Anchorage-Fairbanks Intertie Punch List Items Dear Mr.Massin: I am in receipt of your letter of December 4,1985 regarding thevariousuncompletedpunchlistitemsontheIntertie. I had been planning to attend the Operating Committee meeting scheduled for January 8,1986,per your letter,however I was advised that the meeting has been changed to January 15,1986.I will be out of town that entire week.In fact,Afzal Khan and I will be meeting with General Electric that week to resolve several of the issues related to the Static Var Systems (SVS). The Power Authority has always acknowledged that several items such as the bus work remain to be corrected at Goldhil]and Healy Substations.However,it would not be prudent to modify the bus configurations until such time that we are confident the SVS problems have been resolved.Mr.Orr of Golden Valley Electric has been repeatedly advised of our intentions relative to this issue. With respect to other remaining issues,the Power Authority will be prepared to respond to these items following our meeting with General Electric.I would be more than happy to attend any subsequent Operating Committee or subcommittee meeting scheduled in March. Please advise the date you wish me to attend such a meeting. Si rely,res David R.Eberle Project Manager cc:Afzal Khan,Alaska Power Authority Ed Morris,Alaska Power Authority PO Box 190869 =701 EastTudorRoaad =Anchorage.Alaska 99519-0869 (907)561-7877 )Understanding the Transmission Access and Wheeling Problem By JOHN A.CASAZZA Institutional and regulatory changes in the uses of the nation's bulk power transmission systems which fail to recognize the technical complexity of the systems and the planning and operating problems involved can be disruptive of system reliability and of economic incentives needed for new facilities and technology.This article reviews basic technical and economic considerations connected with the transmission access problem. We are entering a period during which significant changes in the uses of transmission are occurring.In some ways the electric power industry may be in the position the American Telephone and Telegraph Com- pany was about twenty years ago with regard to its long-distance service.A key question is,"Are we headed for a 'bust up'of the world's largest and best transmis- sion system with its highly sophisticated and tested in- stitutional arrangements?” The basic precepts that must be recognized are: 1)The transmission system is a valuable and impor- tant asset to our electric power systems.It must be used wisely. 2)The economic welfare of all consumers is of para- mount importance.The large industrial consumers who use very large amounts of electric power rank high on the list of concern.If they are not eco- John A.Casazza is president of Casazza,Schultz and Associates,Inc. He was formerly an executive with Stone and Webster Management Con- sultants,and for thirty years was with Public Service Electric and Gas Com- pany where he served as a corporate officer.He has served as chairman of the Edison Electric institute Sys- tem Planning Committee,the PJM Coordinated Planning Committee,and Ea the Institute of Electrical and Electronic tome:Engineers Energy Committee.Mr.Casazza attended Cooper Union School of Engineering and received a BEE degree from Cornell University. OCTOBER 31,1985-PUBLIC UTILITIES FORTNIGHTLY nomically healthy,they will not provide the jobs that provide the income to the residential custom- ers,and the shopping centers,and the taxes for vital local and state programs. A Technical-Institutional Problem Like many other utility problems,the question of transmission access and wheeling is a combination prob- lem.It has institutional components and it has technical components.Among the institutional components are the questions of regulation by states and by the federal government,of ownership,of contractual rights,and of obligations to one's neighbors versus one's own cus- tomers.Among the technical components are the need for safe operating procedures and methods,a viable basis for planning the system,and a recognition that new technology may be needed as a result of these changes in transmission uses.The most important thing to recognize is that coordinated technical and institu- tional solutions will be needed. Institutional solutions,regulations,court decisions, contracts,et cetera,which do not recognize the com- plex technology of our bulk supply transmission sys- tems,and the problems of operating and planning these systems,can be dangerous and hazardous both to the reliability of our transmission systems and to providing sufficient economic incentives for the newfacilities and technology which will be vitally needed. The Nature of Transmission Networks Almost the entire U.S.transmission system is com- 35 prised of AC transmission lines.While there are a few DC transmission lines which have local significance,DC does not play an important national role in the trans- mission of electric power in the USA. Parallel Paths A simplified representation of a typical AC transmis- sion system is shown in Figure 1.The division of flow in AC systems is governed by the laws of science, "Kirchoffs Laws.”These laws determine how electric power divides between the various alternate paths.For example,if 1,000 megawatts of power is transmitted from Ontario Hydro to the New York Power Pool,it will divide as shown in Figure 2.It is interesting to note that about one-half of the 1,000 megawatts will flow west and come to New York via Ohio,West Vir- ginia,Virginia,Pennsylvania,and New Jersey.In this situation,the transmission systems of a great many dif- ferent utilities will be utilized by the organizations mak ing the transfer.This type of division of flow ove available paths occurs on all AC systems whether th transfer is of 1,000 miles or ten miles.The reason fc this division of flow is the relative impedances and loa ings of the various paths. In an actual transmission system,there are man transfers going on at the same time;e.g.,from genera ing plants to substations in a given system as well ; between systems.Each of these transfers results in flo over many parallel paths.The algebraic summation + these various flows causes actual loadings on the ind vidual transmission lines. How Much Power Can a Transmission Circuit Delive The amount of power a single transmission circt can deliver is generally not meaningful.Since transm: sion circuits are arranged in networks,the importa Figure 1t - ° QUEBEC Chateauguay ONTARIO Saunders et Bunce Creek =|LfLeMosesMICHIGANSi.Clae om Messena Ceotrott odemomemcmimcad NEW YORK OHIO Ashtabula PENNSYLVANIA Cabot west Kammer VIRGINIA WEST VIRGINIA Harrison Cloverdale Northeast USA -Major Geographic Aree And Key Transmission MARYLAND ast rss . SE coe Baye =a 705 ,sooVIRGINIA EEE "5S _eamsae 200 een 115/138 36 tg Shen BFEACS| PUBLIC UTILITIES FQRTNIGHTLY +OCTOBER 31, Figure 2 Division of Flow from Ontario Hydro to The New York Power Pool for A 1,000-Megawatt Transfer question is how much power can be delivered by the portion of the network under consideration.For long- distance and interregional transfers,this capability has been called by the North American Electric Reliability Council the "network transfer capability.” The amount of power that can be transmitted from one point to another is limited by one of three factors: *The "thermal”loading on a particular circuit.(The amount of power that can be transmitted is limited by its heating effects which can damage the con- ductor or cause excessive sagging.) *The voltage resulting at the receiving point.(This depends on the power factor of the load and the reactance of the transmission system.) *Stability limitations.(Generators can become un- stable if excessive power is carried on a transmis- sion system and certain types of system faults occur.) The transmission systems in the USA are generally planned and operated based on a "single contingency” criterion.This is required to meet acceptable reliability standards.As a result,system loading will be kept be- OCTOBER 31,1985 PUBLIC UTILITIES FORTNIGHTLY low a limit that will be safe for at least a 30-minute period if any single component is lost. Because the flow of power divides in accordance with Kirchoff's Laws through a multitude of parallel paths having different carrying capacity,a great many trans- mission circuits in a transmission system will be loaded considerably below their safe limits even though load- ing or single contingency potential loading on some other individual circuit prevents any further transfer of power. Loop Flow In actual system operations,the summation of the flow over the various paths causes an effect called "loop flow.”Loop flow is a circulating power around a closed transmission path.Referring to Figure 2,the actual di- vision of power can also be visualized as broken into two components,a direct flow of 1,000 megawatts from Ontario Hydro to the New York Power Pool,on which is superimposed a 500-megawatt counterclockwise loop flow.Net loop flows around Lake Erie have varied in the past from as much as 1,000 megawatts clockwise to 1,000 megawatts counterclockwise.Similar magnitudes and variations in Joop flows have occurred on the West Coast and in other parts of the country. Basic Types of Transmission Systems Transmission systems may be broadly categorized into two types.The first kind of system can be called a "network”system.This sort of transmission system is quite "dense,”consisting of a significant number of lines in parallel and involving shorter distances.An example of such a network is the Pennsylvania,New Jersey, Maryland Interconnection (PJM pool).Generally such a network is capable of delivering power from any gener- ating source in the network to any load in the network, and can be operated to produce electricity in the most economic manner. Network systems are tied together by transmission lines which constitute the second basic type of facilities: interarea ties.Referring to Figure 1,only the interarea ties are shown.The network systems are in the "blocks” and are not shown in detail.The interarea ties in most cases have limited capacity when compared to the load or generating capacity in the network areas they usu- ally connect.In other cases,the flow over the interarea ties is limited by local network system facilities. Control Areas A control area is a portion of an electric power sys- 37 tem completely bounded by appropriate metering facili- ties and having within the area sufficient generation under automatic control.Its objective is the mainte- nance of the total power flow in or out of the control area at a specifically scheduled amount,increasing generation if system frequency declines and lowering generation if system frequency increases,both in accor- dance with preset proportionality constants.If no pur- chases or sales are being made outside the control area, the algebraic sum of the power flowing on the intercon- nections should be zero.If an import or export is sched- uled,the generator units under control (the regulating units)are used to maintain the correct total flow on the interconnections.A control area cannot control the di- vision of power over individual AC circuits since the control area regulates only the total flow over all the interconnections crossing the boundary. The number of control areas that exist in a region do not determine the economic dispatch or commitment of generating units.The specific generator units to be op- erated and the economic exchanges between utilities at any time are scheduled by the operations centers of each system,as discussed in the following subsection ("Reliability Considerations”).There may be a large number of utilities performing economic dispatch and unit commitment within a control area (for example, the PJM region).Or there can be a large number of control areas in a relatively small geographic region (for example,the VACAR region). There are no technical reasons why having a large number or a small number of control areas will limit the ability to achieve optimum economic dispatch within reliability constraints. Reliability Considerations Electric power systems must provide adequate capac- ity and adequate energy to consumers.Capacity is pro- vided through investments in facilities to convert fuel or other energy resources into electricity and facilities to transmit and deliver electric power.Energy is pro- duced from various types of fuel or renewable resources such as hydropower.Reliable transmission systems must be planned and operated so that adequate capacity is provided to the consumer along with adequate energy. The transmission systems in the USA were almost entirely developed based on delivering the required ca- pacity to the load area under both normal and emer- gency conditions.The network areas were initially de- veloped so that each system could supply its own load from its own generation,The interarea ties were usu- ally installed to take advantage of the diversity in the outages and the diversity in the time of peak loads for the various network systems.This frequently required they be operated at tess than maximum possible load- 38 ing to provide the needed reserve transmission capabil- ity for generation or transmission outages. More and more,larger than anticipated fuel cost dif- ferentials are changing the basis on which transmission systems are operated.The use of transmission systems to deliver energy rather than capacity is causing very different patterns of power flow and different loading conditions than those that the systems were originally designed to meet.Transmissions systems that are loadec with the flow of low-cost energy may not be able t« perform their capacity functions.This can have a very significant effect on overall system reliability.This situ ation requires a balancing of the systems'capacity re quirements,which determine the reliability of supply t« the public,and the delivery of low-cost energy (calle economy power),which directly affects the cost to th: consumer. In order to plan a reliable power system,advanc information is needed concerning the sources of powe and its points of utilization.Based on this informatior plans can be developed to provide the facilities needec Because of the large lead times on electric utility sy: tems -e.g.,more than ten years for base-load generi tion and more than five years for new transmissio circuits -it is generally not possible to add addition. facilities on only a few years'notice to meet new tran: mission requirements.It is therefore essential that tran: mission uses be known in advance. In order to operate an electric power system reliabl information on conditions on the system must be co tinuously available at a systems operations center.T! operations center must also have the authority to dire system operations at all times so as to maintain syste conditions within safe limits.This must include the a thority to schedule power sources,power transfers,mai tenance Outages,et cetera. System operations are complicated because of t complexity of transmission systems in which operati decisions made in one area have significant effects other areas,as illustrated by Figure 2.Experience | shown that size of the system under one operatic center or the size of the control areas is not nearly important as the coordination of operations betwe the systems.One approach is to have a large centr ized operations center which controls many indep dent systems.PJM and the New England Power P: provide examples of this approach.Such an arran ment is possible even if there are many separate conl areas within the system.Another approach is a num' of smaller operations centers which coordinate ami each other,any one of which may have responsibi for only a portion of a control area.The WSCC ; VACAR regions provide examples of this approach.B approaches have successfully achieved both reliable . economic system operation. PUBLIC UTILITIES FORTNIGHTLY - OCTOBER 31,- Nature of the Institutional blem Development of Transmission Systems The transmission systems in the USA were developed initially to connect local electric power sources to local load areas (network systems).The savings in required generating capacity resulting from equipment outage and load diversities became apparent quite early,leading to the installation of transmission lines between network systems (interarea ties).As the sizes of generator units and the distances involved increased,additional!circuits of higher and higher voltages were installed leading, through an evolutionary process,to the extensive net- works and interarea ties existing today. Ownership of Transmission Systems Transmission systems have been generally installed by the owners of the systems which required the trans- mission,including investor-owned,federal government, state government,and municipally and cooperatively owned systems.In many cases,those who made invest- ments in these systems took risks.In some cases,these were technical risks:Would the system work properly? Would the outage rates be too high?Examples of signif- icant technical risks are the AC and DC Pacific Interties and the American Electric Power 765-kilovolt system. In other cases,large economic risks were taken:Would the forecast load growth or the diversities of load or the fuel cost differentials that were forecast actually occur?An example of such a risk is the PJM 500-kilovolt system. In general,the benefits from transmission and inter- connections have turned out to be considerably greater than originally projected.Procedures for allocating these benefits should be such that utilities are encouraged to take similar wise risks in the future.This can only be achieved if the benefits resulting from wise risks be retained by the consumers and stockholders of the or- ganizations which took them.It seems entirely appro- priate that the consumers and stockholders should con- tinue to retain the benefits from past wise risks taken by the management of these organizations. Right to Use Transmission Systems There are a large number of situations where the participation of a number of utilities were required to develop a transmission system,consisting of a number of lines and substations.In such cases,the owners of the various lines and facilities have developed contrac- tual arrangements for sharing the use of each other's facilities.Among such arrangements were the 1927 con- tract governing the original PJM 220-kilovolt Ring and OCTOBER 31,1985-PUBLIC UTILITIES FORTNIGHTLY agreements of Intertie. Recently,a number of utilities have found that their transmission rights were of greater value to other sys- tems because of changing conditions.As a result,they have put their transmission rights up for "sale”through an open bidding process under which the highest bidder would obtain them.Such a transaction has recently taken place and has been approved by the Federal En- ergy Regulatory Commission:the sale of 500-kilovolt transmission rights from the Baltimore Gas and Elec- tric Company to the Public Service Electric and Gas Company. "960s covering the massive Pacific Regulation and Competitive Forces Since the mid-1920s transmission system development has occurred under a framework of state and federal regulation.Various branches of government have ap- proved rates,approved contracts governing cost alloca- tions and operations,approved the need for lines,ap- proved the routing,approved the design,approved the safety,et cetera,for transmission.The principal pur- pose of this regulation has been to protect the overall public welfare and the rights of consumers. American industry has been tightening its belt,both in terns of the amount of energy it uses and the price it pays.It has been looking at ways to lower its elec- tricity costs.A partial cause for this effort has been the practice of many utility commissions to assign a larger portion of utility costs than their fair share to industrial consumers.As part of this effort industry has been look- ing at the purchase of power from other than their normal supplier and the wheeling of this power to their plants. A number of utilities have large generation reserves that resulted when expected loads did not materialize. These utilities have to pay the fixed costs for this gen- erating capacity.The availability of additional wheeling capacity could enable these utilities to make increased off-system sales.As long as such sales are priced higher than operating costs,they can provide some revenue to help pay for fixed costs. In some cases,large amounts of cogeneration are being installed,larger amounts than can be absorbed by the system in which they are located.When this occurs,the buyback rates for cogeneration will be higher in other neighboring systems,and cogenerators will seek wheel- ing capacity that will permit them to make energy and capacity sales at the highest possible price. A number of state regulatory commissions are initiat- ing efforts to increase the exchanges of low-cost energy between utilities in the state through increased wheel- ing.These efforts are being made through the initiation 39 re | of special studies to dr possible. nine if such exchanges are Obviously,because our transmission system capacity is limited,wheeling for one purpose reduces the ability to wheel for another.Thus,the objectives of the large industrial consumers,the utilities with excess generating capacity,the cogenerators,and the state regulatory au- thorities can be in conflict in specific situations.Fur- ther,these objectives can be in conflict with the direc- tives of Congress that regional coordination is required among operating systems,since intrastate wheeling can utilize transmission capacity which could produce greater savings if used for interstate wheeling. Summary of Institutional Problems The institutional problems involved with transmis- sion access and wheeling are therefore concerned with: *The rights of the owners of the facilities,including their customers and stockholders. *The rights of those who have contracted for a use of all or a portion of the facilities. *The rates to be charged for wheeling and third- party access. *The rules and regulations of the various regulatory authorities,both federal and Jocal. *The efforts of small utilities and municipal utilities to lower their costs of electricity. *The efforts of large consumers to lower their costs of electricity. *The efforts of utilities and large cogenerators to sell their surplus generating capacity at the best possible prices. *The efforts of state:regulatory authorities to im- prove the exchange of low-cost energy between util- ities in a state. *The conflicts between intrastate optimization de- sired by state commissions and the interstate opti- mization desired by FERC. Nature of Technical Problems The nature of the technical problems resulting from wheeling depend on a number of key factors.These are discussed below. The Number and Magnitude of Transfers The technical problems resulting from wheeling obvi- ously depend on the number of arrangements that in- volve a particular transmission system and the magni- tude of the transfers.The effect on system reliability and on system economics can increase significantly as the number and size of the wheeling transfers increase. 40 The Typ "°Systems Involved For "network”type systems having a large numl of relatively short lines,the wheeling of small amou: of power does not constitute a significant reliabil problem.In most cases such transfers will not be sigr icantly different from load variations within the n work area.They can,however,have significant e nomic effects on the customers of the systems involv because of the resulting losses in revenue to the utili For "interarea ties'between network systems invo ing longer transmission distances and limited transm sion capacities,the reliability and economic effects wheeling can both be significant.They can affect op: ating costs by requiring significant changes in dispat: They may also increase capital costs by requiring tra) mission system additions or rearrangements. The wheeling of significant electric power and } availability of transmission access to nonutilities c affect every aspect of utility operations,including: *The planning of the system. *The operation of the system. *System reliability. *System costs and economics. *Rates to consumers. *Financing requirements. The key technical problems are: The Effects of Parallel Paths And Loop Flow Since it is not possible to schedule the flow ov specific paths or to contract for the use of specific lin: the proper planning,operating,and allocation of pz ments for wheeling service becomes a difficult proble The problems of one area can affect other areas. Losses Because transmission system losses vary as the squz of the current,the incremental transmission losses ass ciated with wheeling transfers on already heavily load circuits can be very high as a percentage of the transi being made.These incremental losses can be sever times the average losses on the circuit or system.T proper allocation of these losses becomes a proble: particularly if it becomes necessary to decide whi transfer should be considered first. Measurement of Transmission Use The measurement of transmission system capacity an art,dependent on the criteria used and a large nu PUBLIC UTILITIES FORTNIGHTLY--OCTOBER 31,1¢ ber of technical assumptions varying from what the ambient temperature will be to the type and location of the fault that will occur.About ten years ago,national agreement was achieved through NERC on how "net- work transfer capability”was to be determined.As a result,there is reasonable consistency in measuring trans- mission system capacity among the regions of the USA. There are,however,no agreed-upon criteria for meas- uring the degree of loading of a transmission system over an extended period of time.As a result,differing views can result among the interested parties as to whether a given transmission system is fully loaded and can wheel power for third parties or not. The Basic Questions The right to use a transmission system belongs to the utilities owning the systems or those who have contrac- tual rights to use the system.Because of the way AC transmission systems operate,the flow of power cannot be scheduled over specific paths resulting in many or- ganizations using the systems of other organizations. The flow of power on transmission systems does not recognize political,corporate,or geographic boundaries. There are three basic issues involved in the questions of transmission use and transmission system access and wheeling. Is the optimum use of transmission being achieved by the utilities to exchange energy among themselves and lower costs to the consumer?(The state utility com- missions are pursuing this question because of their con- cern that the maximum possible exchange of economy power be made by the utilities.) Should increased access to transmission systems be available to third parties (nonowners}to make it possi- ble for them to obtain capacity or energy (or both) from more remote sources?(This question is being pur- sued by the large industrial consumers and some mu- nicipal utilities because they believe it offers a means to lower their costs.) Are there ways to reduce regulation and increase com- petition in the electric power industry by controlling the use of transmission systems?(Some segments of gov- ernment,the utilities,and industry believe that reduced regulation and more competition will improve trans- mission utilization and lower overall electric power costs.) There are considerable areas of overlap between these issues.Often technical or institutional changes which will be beneficial in one respect will be harmful in another. Conditions for Transmission Access and Wheeling All parties are in full agreement that wheeling and OCTOBER 31,1985-PURBLIC UTILITIES FORTNIGHTLY transmission access should be accomplished in a techni- cally sound manner and that economic compensation should be fair and equitable to those providing the trans- mission service. There are significant differences in opinions concern- ing what constitutes technical soundness and fair com- pensation.A significant cause for these differences is the lack of technical understanding concerning the plan- ning and operation of power systems.Many view elec- tric transmission lines like-pipelines,with a flow which can be scheduled and controlled.As discussed above, the nature of electric power systems is such that this view is not correct. There are significant differences in the various views on what constitutes fair and equitable charges for trans- mission service.This is essentially a rate question and the establishment of fair rates is a complex art.The various regulatory commissions will have a strong voice in this question.These rate decisions must,however,be based on sound technical grounds. The accompanying table presents a number of possi- ble criteria we have compiled based on our review and discussions with the groups involved for use in achiev- ing agreement on the feasibility of transmission access and wheeling,both technically and economically. Potential Areas for Institutional Innovation There are a number of possible institutional innova- tions that may be worthy of further consideration. Among these are: The Formation of "Transmission Pools” A "transmission pool”would be an organization in which a number of organizations participate to provide transmission services.The pool agreement would spec- ify the conditions for planning,operation,charges for services,et cetera,on a coordinated basis.Such an ar- rangement would be similar to present power pools but would not involve a generating capacity.Specific exam- ples of a sort of "transmission pool”exist in California with the Pacific Intertie and in the PJM area with the 500-kilovolt transmission system. The "Swedish”Approach With this arrangement,membership in the transmis- sion pool pays for transmission services.Membership in the pool requires a large entry fee and five years notice for long-term transmission requirements.Severe economic penalties are also included if an organization uses more transmission capacity than for which it has contracted. Possible Criteria for Provision of Transmission Access and Wheeling Requirements of Technical Policy 1)To use and access transmission,requests must be made sufficiently in advance to allow system plans to provide adequate capacity. 2)The acceptability of a transfer on existing facilities from a reliability viewpoint should be decided by the organizations having the responsibility for operating the portion of the system involved.This responsibility should also include the responsibility of selecting from among a number of available transfers when all cannot be safely accomplished,the ones producing the greatest overall saving.Procedures need to be developed to fairly compensate those whose transfers are not made in order to make possible a larger saving. a PRR 2 Arrangements for Sale of Transmission Rights through Open Bidding As previously discussed,the sale of transmission rights has recently occurred based on open bidding.Further implementation of this process so that the bidding would include the largest possible number of users would be desirable.Such an implementation should thoroughly evaluate the many long-range technical and economic effects of such a procedure. Conclusion The issues of transmission access and wheeling have been growing in importance and are likely to be with us for many years.Temporary short-term solutions can be dangerous,leaving us with institutional arrangements and technical solutions that result in long-range ineffi- ciencies and extra costs to the public.Research to assess the long-range effects of proposed solutions is desirable, considering long-term future trends and technology changes in electric power systems. Because of the combined technical and institutional nature of the problem,long-range technical solutions must also recognize the institutional requirements,and Requirements of Fair Compensation 1)If additional capital expenditures must be made. those for whom they are made should pay for them,even it their needs change.(A "take-or- pay”requirement.) 2)if existing facilities are utilized for wheeling transactions,and if such transactions affect the ability of the owners of the transmission to make alternate transactions,the transmission should be used to achieve the maximum economic savings.In such cases,the owners of transmission rights who relinquished their use of these systems should be compensated based on the savings which they forego plus a portion of the additional savings they make possible. (The open bidding process tor sale of transmission rights is an effective way to achieve this.) 3)Wheeling rates should include compensation for the risks taken by the original consumers and stockholders,and should recognize the significant increase in the value of the services being rendered. vice versa.How our transmission systems should | developed depends on how they are to be used in tl future. A significant cause of transmission access and whe ing problems is that many of the organizations,regul tors,legislators,judges,economists,attorneys,and i dustry policymakers lack a good understanding transmission systems.We hope some of the backgrou: in this article will help these decision makers in und standing the difference between various types of trai mission systems,the problems of transmission syste planning and design,and potential ways for improvi the usefulness of our transmission systems for the ber fit of all consumers.Only through a better understar ing among those involved in this problem of the ma significant areas of agreement among them,along w areas of disagreement,can a sound basis be provi for future decisions. AUTHOR'S ACKNOWLEDGEMENT:The author grateft acknowledges the helpful cooperation of many.indi uals in the investigations that formed the basis for : article,particularly Dr.R.A.Wakefield,and P.].1 ermo of Casazza,Schultz and Associates,Inc.,ane Young of the Electric Power Research Institute. 42 PLOUIC UTI TT Tete Policies Governing Transmission Access and Pricing:The Wheeling Debate Revisited By JERRY L.PFEFFER Rising electricity prices,intersystem embedded cost differentials,surplus generating capacity,and efforts to promote competition in bulk power markets are among the divergent factors contributing to renewed interest in policies governing transmission access and pricing. The electric power industry has undergone consider- able changes in the fifty years since Congress first ad- dressed the wheeling issue in debate leading to enact- ment of the Federal Power Act of 1935.As a result of major technological innovations,fundamental changes in the economics of electric power supply,and a grow- ing political bias in favor of market solutions over gov- ernment regulation,we are beginning to observe a clear trend towards greater competition in segments of the electric power industry.This competitive trend is char- acterized by: *Increased competition among utilities to serve new and existing loads,especially in terms of marketing excess capacity off system. ¢Interest in constructing new capacity specifically ©Jerry L.Pfeffer is a principal with Pfetfer,Lindsay and Associates,a con- !sulting firm specializing in economic H and regulatory policy matters affect- aa ing electric and gas utilities.He pre- Bm viously served as assistant adminis- M trator for utility systems at the Depart- a ment of Energy.He has also served A as assistant to the chairman of the Synthetic Fuels Corporation and as Agee director of utility studies at the Mitre seam Corporation.Mr.Pfeffer holds an HE undergraduate degree in engineering -q and a graduate degree in regional =planning and managerial economics §trom Cornell University. for making long-term coordination sales to othe: utilities.2 *Efforts by wholesale and retail customers to "sho; around”for lower-priced power or consider self generation as alternatives to purchasing from thei current supplier. *Projected growth in nonutility-owned cogeneratio: and small power production under Title Il of the Public Utility Regulatory Policies Act.? *Increased regulatory reliance on "competitive”o "marketplace”standards in the rate-making treat ment of new plant.3 This article will provide a brief overview of the grow ing debate concerning proposals to adopt less restrictiv: transmission access and pricing policies as a means 0 promoting competition in bulk power markets.In par Several proposals for development of new capacity dedicated t serving the wholesale market have been reported.These include proposed 2,000-megawatt coal project in Nevada under consideraticbySierraPacificPowerCompanyandasimilarsizefacilityinNeMexicobeingstudiedbyajointventureincluding:Public Servi:Company of New Mexico,General Electric Company,Bechtel GrouInc.,and the Navajo Indian Tribe.2Approximately 20,000 megawatts of capacity have been grant:qualifying facility (QF)status under §201 of PURPA although muofthismaynotbebuilt.In states such as Califomia and Texas,large percentage of future capacity needs will be derived frononutility-owned generation developed with the assistance of PURP benefits. 3Such "market pricing”standards have been adopted by regulatoinMassachusettsandMontanaandareunderconsiderationinCa fornia and several other states.See "Strategies for Advance Pow Plant Review and Certification,”Pfeffer,Lindsay and Associates,In report prepared for the Michigan Energy Administration,April,198 pp.64-70. PUBLIC UTILITIES FCS ticular,we shall focus on the c.-licting perceptions of economic efficiency and equity which have contributed to disagreement over the appropriate criteria for setting public policy in this area. Wheeling Money versus Wheeling Power There is growing interest in both the adequacy and efficiency of utilization of the nation's high-voltage transmission network and its role in promoting greater competition and efficiency in electric power supply.Un- der current law,utilities are generally not obligated to transmit power between noncontiguous buyers and sell- ers -a service generally referred to as "wheeling.”4 The lack of assured wheeling service on reasonable terms has long been viewed by some economists and regula- tors as the major impediment to increased bulk power market competition.5 Others,however,question the fair- ness and efficiency benefits of such "competitive”mar- kets,absent parallel changes in industry structure and in government policies relating to utility service obliga- tions,rate design for requirements sales,and prefer- ences accorded to selected market participants. Recent proposals for adopting new guidelines.to gov- ern the price and nonprice terms of transmission service reflect efforts to expand the range of competitive op- portunities for both buyers and sellers in bulk power markets.Many of these efforts involve increased econ- omy energy transfers which would either displace higher- cost generation on the purchasing system with lower- cost power from other utilities or use purchased power from systems with "surplus”capacity to defer construc- tion of new generating capacity or retire obsolete units. In these sorts of voluntary coordination transactions, which are based on marginal cost differentials between buyer and seller,wheeling typically results in more effi- cient production and lower-cost power supply. However,much of the recent demand for increased access to transmission and less restrictive terms for trans- mission service has little to do with enhanced efficiency or reduced costs.This demand is originating among full requirements wholesale customers and large retail cus- tomers seeking to "shop around”for a lower embedded cost rate than offered by their current supplier. Wheeling transactions based on average embedded 'Wheeling is typically defined as the transmission of energy orcapacityofanothersupplieronaprearrangedbasistothesystemof a third party.If the third party is a partial requirements customer, the wheeling utility provides a transmission path for energy flow.If the third party is a full requirements wholesale or retail customer,it must also provide a generation control function to affect the desired energy transfer. 5A 1981 survey of the literature dealing with competition and anti- trust issues in the electric power industry concluded that there was virtual unanimity with regard to the importance of mandatory wheel- ing obligations as a prerequisite to competitive markets.See,"Anti- trust and the Electric Utility Industry,”by Joe D.Pace,presentation to the Edison Electric Institute Legal Committee,April,1981. OCTOBER 31,1985-PUBLIC UTILITIES FORTNIGHTLY cost differentials as distinct from marginal cost dif- ferentials -do not promote greater economic efficiency. Rather,they simply redistribute the "benefits”of lower embedded cost power without reducing the overall cost of power generation.In the words of Federal Energy Regulatory Commission Commissioner Charles G.Sta- lon,such transactions constitute "wheeling money”ver- sus "wheeling power.”Indeed,the transaction costs and energy losses from such transactions may actually in- crease overall power supply costs.They may also im- pose higher costs on the other customers of the wheel- ing utility as a result of reallocating a pro rata share of fixed costs incurred by the wheeling utility pursuant to its service obligation to those customers now seeking to purchase off system. The most recent entrants into the market for trans- mission service are the growing number of qualifying cogenerators and small power producers (QFs)seeking to wheel their output to the purchaser offering them the highest price (net of transmission costs).To the degree that power sales by a QF displaces generation with a higher incremental cost,such wheeling transac- tions promote economic efficiency.However,if the pur- chasing utility's mandated "buyback rate”under §210 of PURPA exceeds its actual avoided cost or the in- tended buyer is a retail customer of the wheeling utility who is seeking to "bypass”that system and purchase directly from the QF at a price which is lower than prevailing (embedded cost-based)retail rates,such wheel- ing transactions for QFs may reduce economic efficiency. In brief,while transmission access on reasonable terms is arguably a prerequisite to competitive bulk power markets,it does not follow that increased wheeling un- der all sets of circumstances will result in more efficient markets that reduce overall power supply costs.Indeed, as suggested above,much of the recent growth in the demand for transmission service may involve inefficient transactions which are contrary to the public interest in assuring economic and reliable electric power.Nonethe- less,those who will benefit from such transactions have invoked a variety of "procompetitive”arguments in sup- port of their demands for greater transmission access. The outcome is a growing political debate over the appropriate policies which should govern transmission access and utilization -debate which increasingly in- volves conflicting perceptions of efficiency and equity among the participants. Evolution of Existing Rules and Practices Although it has considered the wheeling issue on nu- merous occasions,Congress has consistently rejected ef- ¢"Some Thoughts and Concerns about FERC Wheeling Policies,”by Charles G.Stalon,presented at the Federal Energy Bar Association midyear meeting,Washington,D.C.,January 10,1985,p.2. forts to impose common,ier or extensive mandatory wheeling obligations on electric utilities throughout the 50-year history of the Federal Power Act.Many utili- ties incurred limited wheeling obligations as part of nu- clear plant license conditions imposed by the Nuclear Regulatory Commission under the antitrust provisions of the Atomic Energy Act of 1954.7 In the 1973 Otter Tail case,8 the Supreme Court held that transmission facilities are "essential facilities'under the antitrust laws when only one transmission system serves a given util- ity and that system cannot be economically duplicated. Among the possible grounds which could be justifiably cited by a utility for refusing access to an "essential facility”-i.e.,refusing to wheel -are (a)lack of adequate capacity,(b)unreasonable interference with utility operations which could not be satisfactorily lim- ited by imposing conditions to the access,and (c)what is referred to as "legitimate business justification.”Be- cause the courts have not provided clear guidance as to what constitutes a "legitimate business justification,”con- cern over potential antitrust liability has made most utilities reluctant to arbitrarily deny wheeling service to other utilities when transmission capacity is available to render the service requested. In 1977,the House adopted extensive mandatory wheeling obligations in its version of the PURPA legis- lation but the Senate rejected similar proposals.The legislation that finally emerged from Conference Com- mittee (§§211-12 of the Federal Power Act)provided FERC with limited mandatory wheeling authority whose exercise was subject to numerous conditions and find- ings.Most importantly,no order may be issued under this authority unless the FERC determines that such an order "would reasonably preserve existing competitive relationships”among the utilities affected by the order.? In addition,no order may be issued which would re- quire a utility either to wheel power to a customer that would replace power the wheeling utility already pro- vides to that customer pursuant to an existing contract or which provides for transmission directly to an ulti- mate (retail)customer. In several cases addressing the scope of FERC wheel- ing authority,the courts have held that the commission may not require utilities to file their individual wheel- 7The NRC imposed license conditions in approximately 30 of thenearly100nuclearplantlicensingcasesconsideredinthe1960sand 1970s as a remedy to alleged anticompetitive problems.In manycases,these conditions included systemwide wheeling obligations forspecifiedparties.See,"Power Pooling in the United States,”FERC,Washington,D.C.,1981,p.58. 'Otter Tail Power Co.v United States (1973)410 US 366,97PUR3d209. %In the only case decided by the FERC among the three applica-tions submitted thus far under §211,the commission denied a re- quested wheeling order because it would have violated the statutoryrequirementto"preserve existing competitive relationships.”See South-eastern Power Administration v Kentucky Utilities Co.(1983)25FERC461,204. 28 ing agreem.-s in the form of a "tariff'°or use i authority under the rate-making provisions of the Fe eral Power Act -e.g.,those relating to "undue di crimination”-to circumvent the statutory restrictio: on its authority to mandate wheeling.!!The commi sion appears to have generally accepted this view of tl limited scope of its mandatory wheeling authority. Renewed Interest in Wheeling Issues The intensity of the 1977-78 legislative debate ov: wheeling policy initially made Congress reluctant to r open the issue in subsequent years.Recently,howeve the level of interest has broadened considerably as result of a number of interrelated economic and polit cal factors including: ¢Substantial intersystem (embedded cost)rate di ferentials in an era of rising electricity pric which encourage "rate shopping”by requiremen customers. *Disincentives for utilities to construct new pla) and opportunities to acquire needed capacity throu; long-term,off-system purchases. *A temporary surplus of lower-cost generation certain regions which some believe could be use more efficiently to displace higher-cost generatic elsewhere;in a few cases,opportunities for su tained (long-term)transfer opportunities are als projected. *Competitive pressures stimulating efforts by electri intensive industrial customers to shop around fi lower-priced power from alternative suppliers. *The perceived success (in some circles)of "dereg lation”and enhanced competition in other indu tries including airlines,railroads,telecommunic. tions,and especially natural gas (where the FER has recently proposed a "nondiscriminatory”acce rule for natural gas pipelines offering third-par: transportation service). *Efforts by QFs located within the service areas : utilities with relatively low avoided costs e.g those with excess capacity -to obtain access other utilities or retail customers offering high: purchase rates. The recent convergence of all of these factors hi resulted in concerted efforts by a diverse set of intere groups to obtain greater access to transmission servi: on reasonable terms. See,for example,Florida Power &Light Co.v Federal Ener; Regulatory Commission (CASth 1981)660 F2d 688. NSee,for example,New York State Electric Gas Co.v Feder Energy Regulatory Commission (CA2nd 1980)638 F2d 388. PUBLIC UTILITIES FORTNIGHTLY --OCTOBER 21.194 Current Scope of Wheeling 'vity The wheeling debate is often complicated by a failure to distinguish among the many different types of trans- mission services offered,a limited awareness of the ex- tensive wheeling services already being provided,and disagreement over how much additional wheeling could be accommodated within existing system constraints. The number of transmission service arrangements on file with the FERC has more than doubled in the past ten years,increasing from approximately 650 arrange- ments in 1976 to 1,380 arrangements in 1985.!2 Our review of filed arrangements suggests that some form of transmission service is already available to most of the nation's major publicly,privately,and cooperatively owned utilities.3 Most of the transmission "arrangements”filed with the FERC are contractual agreements among specific parties to provide designated service(s).The terms and conditions of such contracts are individually negotiated to reflect the needs of the parties,bulk power market conditions,and the engineering and load characteristics of the relevant systems.In most cases,transmission ser- vice agreements specify the prices charged for the ser- vice as well as such nonprice terms as notice and sched- uling requirements,contract duration,minimum and maximum loads,firmness,et cetera.A limited number of arrangements filed with the FERC are "wheeling tar- iffs.”These constitute an offer by a utility to provide one or more specific types of wheeling service to any eligible party under uniform terms and conditions which are specified in the tariff. The amount of energy wheeled by private utilities under these arrangements has also shown substantial growth in recent years -both in absolute terms and as a percentage of total kilowatt-hour sales.For example, between 1973 and 1983,the amount of energy wheeled increased by 153 per cent compared to a 23 per cent increase in sales to ultimate customers.Between 1961 and 1983 the amount of energy wheeled increased by approximately 1,200 per cent while total energy sales increased by only 200 per cent.!4 Additional wheeling (not reported in published transmission service statis- tics)routinely occurs within formal power pools and among the member companies of holding company sys- tems.Also excluded from published data is the substan- tial amount of energy transferred between noncontigu- 12"Index of Filed Electric Rate Schedules,”Federal Power Commis- sion,Bureau of Power,September,1976;FERC,Office of Electric Power Regulation,June,1983.Many of these arrangements are recip-rocal service agreements. "Survey of Transmission Services Provided by Investor-ownedUtilities,”EEl,report prepared by Pfeffer,Lindsay and Associates,Inc.,December,1984. MStatistics of Privately Owned Electric Utilities,”FPC,(selectedyears),"Financial Statistics of Electric Utilities,”U.S.Department ofEnergy,1983. OCTOBER 31,1985-PUBLIC UTILITIES FORTNIGHTLY ous systems in t orm of simultaneous purchase and resale transactions.Thus,under any reasonable mea- sure,the utility industry today is making substantially greater use of wheeling services for consummating eco- nomic bulk power transactions than it did ten or twenty years ago.}5 FERC Regulation of Transmission Pricing The rates charged for transmission service are subject to exclusive commission jurisdiction under §205 of the Federal Power Act.There are a variety of rate struc- tures used by utilities in charging for wheeling service,!® the most common is a "postage stamp rate”under which a customer is charged a fixed rate per unit of service; e.g.,mills per kilowatt-hour for nonfirm wheeling or dollars per kilowatt for firm wheeling.In approving rates for firm power wheeling,the FERC has employed an (embedded)"rolled-in”costing methodology;i.e.,all transmission-related costs are aggregated and uniformally allocated to firm transmission customers based on their respective demand.The commission has also approved numerous transmission rate schedules utilizing the costs of specific transmission facilities where it can be argued that those facilities are the principal ones employed in providing the service.In either case,however,the com- mission uses the embedded or "book”costs of the rele- vant facilities of system in setting transmission rates (rather than marginal costs). In the case of nonfirm wheeling,the policy of the commission with regard to recovery of any capacity- related costs is unclear.In two cases,the commission has issued conflicting decisions on this issue leading to a court remand directing the commission to reconcile the apparent conflict.?7 Commission policy with respect to the use of "per- centage adders”in wheeling rates became an issue fol- lowing significant price increases (as a result of com- pounding effects)in fuel displacement transactions during the 1973 oil embargo and the 1977-78 coal strike.As a result,the commission has adopted rules eliminating the use of percentage adders in rates for transmission of For an excellent survey of recent coordination sales involvingwheelingservicesvoluntarilynegotiatedamongpublicandprivate utilities see,"Meeting Future Power Supply Needs:Long-distance Pur- chase,Sale,and Transmission of Electric Power,”by Kirk Howard Betts,paper presented to the annual meeting of the American Public Power Association,May 6,1985.Betts cites a number of successful deals recently negotiated,but notes there remain both "technical”and "philosophical”barriers to obtaining needed transmissicn service. \6For a detailed review of FERC transmission pricing policies see, "Analysis of Power Wheeling Services,”Oak Ridge National Labora- tory,report prepared for FERC,1984;and "A Review of Current Practice and Emerging Issues in the Design of Rates for Transmission Service,”Pfeffer,Lindsay and Associates,Inc.,report prepared for EEL,1985. 17See,Kentucky Utilities Co.(1978)15 FERC 4 61,002;Florida Power &Light Co.(1982)121 FERC §61,070;affirmed,Fort Pierce Utilities Authority v Federal Energy Regulatory Commission (1984) 730 F2d 778. 29 fuel conservation energy)®and restricting percentage add- ers to one mill per kilowatt-hour in wheeling and purchase-resale transactions (unless the wheeling util- ity can justify higher costs).!9 An increasingly common method of pricing the wheel- ing of economy energy is to permit the wheeling utility to participate in the shared savings of the economy energy transaction by charging a percentage -e.g.,15 per cent -of the net savings (after payment of losses). In several recent cases,the FERC has also accepted "value-of-service”based transmission rates in transac- tions other than economy energy including the use of a competitive "bidding process”to market excess trans- mission capacity”and explicitly recognizing the oppor- tunity costs associated with alternative uses of trans- mission capacity.2? Obstacles to Additional Wheeling There is little empirical evidence to support argu- ments of substantial "unexploited opportunities”for eco- nomic bulk power transactions that are constrained solely by reliance on bilateral contracting for coordina- tion sales,restrictive transmission access policies,un- reasonable wheeling rates,and conditions or related industry practices which arguably inhibit effective coor- dination.Even if these practices were modified,the po- tential short-term increase in economic transactions may not be very great in relation to existing coordination sales.Thus,the overall national savings in electric power supply costs would be relatively small,although sav- ings to individual utilities (especially smaller systems) might be substantial.22 The largest percentage of otherwise economic coordi- nation transactions which are not being consummated are more likely inhibited by the physical limitations of existing transmission capacity as distinct from policies and practices which inhibit effective coordination.Most of the existing transmission lines linking areas of high incremental cost and lower incremental cost generation -e.g.,Northwest to California,Midwest to Middle- Atlantic,et cetera -are already fully loaded with oil and gas displacement transactions."Efforts to construct new W'Order Establishing Principles for Fuel Conservation Energy,”FERC,Docket No.ER78-229 et al.,1980. WFERC,Docket No.ER79-29,Final Rule,Order No.84,1980. *Baltimore Gas &Electric Co.(1984)28 FERC §61,096. 21Pennsylvania-New Jersey-Maryland Interconnection (1984}28 FERC 4 61,205. 2For example,in a 1981 study,FERC staff estimated that if all"unrealized”coordination sales were consummated,the overall sav- ings to U.S.ratepayers would be in the range of one to 2 per cent ofelectricrevenues.See,"Power Pooling in the United States,”op cit,p.166. 2See,for example,"East Central Area Reliability-Mid-Atlantic AreaCouncilInterregionalPowerTransferAnalysis,”presented to DOEbytheECAR-MAAC Coordinating Group,June,1985.This reportdocumentstransmissionlimitationswhichconstrainadditionaltrans- fer of oil displacement energy between the Midwest and Mid-Atlanticstates.Similar studies have been performed for other regions by therelevantreliabilitycouncilsandutilities. 30 transmission capacity are proceeding but have encour tered growing opposition based on environmental,healt! and safety concerns.The North American Electric Rel ability Council has reported delays of as much as te years in the in-service dates of a number of importa: transmission lines whose completion would substantial! increase the energy transfer capability of the existir transmission network.24 Even if siting and licensing problems could be r. solved,intervening utilities located along major eners transfer corridors might still need substantial econom incentives -e.g.,a share of the savings derived fro coordination transactions -to make it worth their whi to invest in new transmission capacity which wou primarily benefit third parties.Further,by the time ne transmission capacity could be completed,much of t! surplus generating capacity currently available for sz would be needed by the exporting system to serve n tive system loads. Another possible impediment to additional wheeli: over existing facilities -and certainly a factor in ut ity willingness to construct new transmission facilit which would be used extensively for third-party whe ing -is the embedded cost basis of transmission s vice pricing.Rates for transmission service which i based on average embedded costs,fail to provide acc rate price signals.Rates based on incremental costs providing service (including the opportunity costs forgone transactions)would result in more efficient 1 of existing transmission capacity and provide neec incentives to develop new capacity. Because the incremental costs of new transmiss: generally exceed embedded costs,embedded cost p1 ing may require a utility's existing customers to sult dize new transmission loads.In some cases,rates ba on embedded costs can be set too high and discour buyers and sellers in coordination markets from eng ing in otherwise economic transactions.Problems st ming from reliance on embedded cost based pricing magnified when a new facility is dedicated primarily third-party wheeling and contributes little to integre system operation.For these reasons,the commissio1 beginning to examine alternative transmission pric concepts based on the use of marginal costs,oppo: nity costs,and value-based rates. In addition to the factors cited above,other poss impediments to expanded wheeling include system | ability concerns from sustained (unidirectional)ene transfers over transmission lines which were gener not designed to accommodate such transactions'5 "Annual Review of Overall Reliability and Adequacy of Power Supply,”North American Electric Reliability Council (sel years). 23Most transmission lines were designed to link generation to centers and interconnect neighboring systems to enhance eco: and reliability.In very few cases -e.g.,Pacific Northwest Inter: was third-party wheeling a primary consideration. PUBLIC UTILITIES FORTNIGHTLY -OCTOBER 31, uncompensated energy flows over the transmission fa- cilities of third parties not on the "contractual path” specified in the wheeling agreement.?®In most cases, these are short-term problems which could be remedied with appropriate investments;but existing FERC pricing policies fail to provide the needed incentives for utilities to make such investments. Arguments Favoring Expanded Wheeling Notwithstanding the substantial level of wheeling ac- tivity already occurring under existing (voluntary)ar- rangements and the physical impediments noted above to additional near-term energy transfers,there is a grow- ing constituency which believes that the transmission grid could be utilized more efficiently to reduce energy costs.The following are among the principal arguments used by wholesale and industrial customers and some regulators,in support of proposals for mandating non- discriminatory transmission access under what are termed "reasonable terms and conditions.”” *First,existing industry structure and operating prac- tices fail to assure that all economic transactions actually occur.Utilities have consistently failed to document their assertions that existing transmission facilities are being effectively utilized to minimize power supply costs. *Second,utility efforts to impose unreasonable terms and conditions often restrict the scope of transmis- sion services actually provided and may effectively negate the relative value of whatever "access”is theoretically available under filed agreements. *Third,wholesale customers have limited bargain- ing power in negotiating wheeling contracts under the existing regulatory scheme where FERC cannot require wheeling service which would upset "exist- ing competitive relationships.”The threat of anti- trust sanctions is a costly strategy with uncertain results where utilities refuse to wheel or fail to negotiate in good faith. *Fourth,industrial customers served by high-priced utilities need assured transmission access to pur- chase lower-priced power "off system”so as to maintain their economic viability and sustain employment. ¢Finally,QFs require guaranteed access to transmis- sion if they are to negotiate sales to the buyer with %The Texas Public Utility Commission has adopted an approach to determining wheeling charges which partially compensates for such energy flows. 2For a more detailed statement of the views of wholesale custom- ers see,"Report of the APPA Transmission Task Force,”APPA,Feb- ruary 8,1984.Industrial customer views on transmission access are outlined in,"Wheeling:Options for Industrials,”Electricity Consum- ers Resource Council,December,1984. *OCTOBER 31,1985 PUBLIC UTILITIES FORTNIGHTLY the highest "avoided cost”within economic trans- mission distance. The Utility Response In response to these arguments,utilities have noted that current voluntary arrangements are working well to accommodate the large percentage of economic trans- actions within existing system constraints.Industry rep- resentatives have offered the following reasons for re- taining existing policies governing transmission access and wheeling obligations.4 ¢First,major transmission paths between high-and low-cost power regions are already fully loaded to exploit the short-term availability of surplus gener- ation.Additional transfers will require construc- tion of new transmission capacity and cannot be "legislated.” *Second,there are no efficiency benefits as a result of obligating a utility to wheel lower-priced "off- system”purchases by its own wholesale or retail customers,if the rate differential is based on lower embedded costs. *Third,the concept of "off-system”purchases by requirements customers is incompatible with the tra- ditional utility service obligation and the long lead times required to plan for new capacity require- ments.A firm service obligation for requirements customers dictates some commensurate purchase ob- ligation by those customers to avoid a reallocation of costs incurred on their behalf to the utility's other ratepayers. *Fourth,mandatory wheeling obligations for full requirements wholesale and retail customers as a means of promoting competition would also dictate a relaxation of service obligations,greater reliance on marginal costs in setting retail and wholesale rates,and elimination of subsidies and preferences to publicly owned systems,cooperatives, and QFs to allow a transition to a competitive market structure.These changes must occur in par- allel with any effort to mandate increased trans- mission access,if resulting markets are to enhance economic efficiency. *Finally,under any type of wheeling policy,a util- ity must maintain control over the use of its trans- mission network to assure reliable system opera- tion.While acknowledging some of the complex operational problems arising under any sort of com- The views of private utilities are detailed in "An Investor-owned Utility Perspective on Intersystem Energy Transfers and Wheeling Issues,”by Douglas C.Bauer,presentation to the National Associa- tion of Regulatory Utility Commissioners Committee on Electricity, November,1984. 31 eeemon carrier schen vheeling advocates have yet to define workable solutions. Legislative Developments Several legislative proposals dealing with transmis- sion access policy were introduced during the 98th Con- gress (1983-84)although none were enacted.Similar proposals are pending or likely to be introduced during the current congressional session.These include: *Mandatory wheeling bill (HR 2231)introduced by Congressman Kostmayer (Democrat,Pennsylvania) would amend §211 of the Federal Power Act to make it easier for FERC to order a utility to pro- vide wheeling service.Specifically,HR 2231 would require FERC to order wheeling which would "in- crease competition in the bulk power supply mar- ket or otherwise serve the public interest.” *Hydro relicensing bill (HR 1815)introduced by Congressman Matsui (Democrat,California)con- tains provisions relating to wheeling obligations and a mandatory FERC and Department of Justice anti- trust review which would be imposed on the new project licensee to "promote competition.” *Regional regulation bill (soon to be introduced)is designed to facilitate creation of multistate com- pact agencies that would exercise regional regula- tion and power supply planning functions.The bill is likely to include provisions through which such regional bodies could petition FERC for mandatory wheeling orders consistent with a regional power supply plan. In addition to these specific legislative proposals,both House and Senate Energy Committees have scheduled broad oversight hearings on a number of utility-related matters during the 99th Congress during which they will address various aspects of the wheeling and bulk power competition issues.It is considered unlikely that any significant legislation dealing with wheeling issues will be enacted during the 99th Congress.Near-term changes are more likely to emerge from federal and state regulatory forums. Regulatory Developments at the Federal Level While Congress has narrowly restricted FERC's au- thority to mandate wheeling,the commission has re- cently sought to identify opportunities to promote greater competition within the scope of its existing stat- utory authority.In December,1984,it approved a two- year "experimental”bulk power market arrangement among a group of southwestern utilities which is de- signed to examine the feasibility of establishing compet- 32 itive mar for certain types of coordination service: In March,1985,the commission published a profile selected transmission service agreements to provide terested parties with greater information on the sce of existing transmission services.2° The most direct evidence of commission interest providing incentives for increased transmission serv as a means of promoting the development of comp: tive markets is found in Phase 1 of its recently iss notice of inquiry (NOI)dealing with its regulation coordination service.*!In addressing this issue,the N begins by noting that,"the availability of transmiss: service is a necessary element of competitive electric markets.”It proceeds to raise a number of fundamer questions relating to (1)the supply of transmission cilities,(2)transmission service pricing,and (3)tra mission access policies. With regard to transmission supply,the commiss seeks comments on how its existing policies affect centives to invest in needed transmission capacity also seeks comments on the efficiency implications alternative transmission pricing schemes for differ types of transmission services.Finally,while noting limited authority to mandate wheeling,the commiss seeks comments on whether the demand for transr sion services is being met,how its existing pricing p cies affect utility incentives to provide wheeling ser voluntarily and the efficiency implications of vari types of transactions and alternative transmission cess policies. The questions raised in the NOI directly address m of the outstanding issues in the ongoing debate o transmission access and pricing policies.Based on accelerated schedules established for the NOI,the th: of recent comments by the chairman and member: the commission and the commission's actions in a ¢ temporaneous rule making dealing with natural gas p line transportation (Docket No.RM85-1),there has t much speculation on the future direction of commis: policy in the transmission area.At a minimum, commission appears determined to use its rate-mal authority to provide incentives for utilities to offer creased transmission access voluntarily on flexible te and conditions that will promote efficient and comy tive electricity markets.At least one member of commission has expressed a clear preference for u marginal costs rather than embedded costs in transi sion service pricing.®2 At the same time,however,the commission has Public Service Co.of New Mexico,Opinion No.203 (198. FERC 4 61,469. 30"A Review of Selected Transmission Agreements,”FERC,Ai 1984. 31Regulation of Electricity Sales for Resale and Transmission vice,”FERC,Docket No.RM85-17 (Phase 1),NOI,May 30, 32See,Charles G.Stalon,op cit.,p.4. PUBLIC UTILITIES FORTNIGHTLY-OCTOBER 31. pressed a clear awareness of ....potential adverse ef- fects of certain types of transmission service;e.g.,wheel- ing for retail customers,wheeling based on embedded cost differentials,et cetera.In other areas,such as the unequal distribution of government-endowed subsidies and preferences among publicly and privately owned utilities,continued reliance on embedded cost rate mak- ing at the retail level and fixed service obligations for requirements customers,the commission has not in- dicated how it will reconcile its competition and effi- ciency objectives with these exogenous factors (gener- ally beyond its direct control)that may result in ineffi- cient outcomes.Overall,the commission is likely to move very cautiously in adopting rules or policies which might indirectly force utilities to provide transmission services which conflict with economic efficiency criteria or unfairly penalize the customers of the wheeling utility. Regulatory Developments at the State Level There is a growing trend among state regulators to examine their own authority to order wheeling.Uncer- tainty over the extent of federal (FERC)preemption in relation to wheeling matters has probably been an im- pediment to more aggressive action at the state level. Several states -e.g.,New Mexico --have adopted new legislation dealing with intrastate wheeling for util- ities.Others -e.g.,Florida,Texas,et cetera -have adopted rules requiring intrastate wheeling from QFs to other utilities but not to retail customers or other facili- ties of the QF.23 In a recent order issued in response to a joint petition from the Florida Public Service Com- mission and the state's utilities,the FERC asserted ex- clusive jurisdiction over all wheeling rates,but did not address the scope of state authority to mandate what is termed "intrastate”wheeling service.Some have speculated that FERC may be willing to "tolerate”com- mission efforts to mandate intrastate wheeling transac- tions specifically authorized under state law as long as its exclusive rate jurisdiction is not challenged. State regulators are increasingly being drawn into de- For a detailed survey of state wheeling authority see,"Wheeling: Options for Industrials,”ELCON,op cit. ¥Florida Power &Light Co.et al.,Docket No.EL84-27 et al., Declaratory Order,October 31,1984. bate over the rela.ed issues of off-system purchases and supplier substitution by retail customers.State concerns regarding the adverse impact on residential customers as a result of off-system purchases by industrial cus- tomers -i.e.,the "industrial bypass”issue -were evident in comments filed by many state commissions in the recent FERC notice of inquiry on gas pipeline transportation. State regulators have also expressed concern regard- ing unsuccessful NARUC efforts to have various indus- try groups compile data to be used in "measuring the effectiveness”of transmission system utilization.The in- dustry has been somewhat reluctant to compile such data because of its concerns over alleged deficiencies in NARUC''s proposed analytic approach.NARUC has in- dicated that it may perform its own study to identify opportunities for increased economy transfers among utilities and assess the need for new transmission facilities. Summary A number of factors have contributed to a renewed interest in policies governing transmission access and pricing.As outlined above,these policies and related industry practices are viewed as a key element in the evolution of competitive bulk power markets.The deci- sions made by Congress and regulators over the next several years in determining the outcome of the wheel- ing debate will also do much to determine the future organization and structure of the electric power indus- try.Reconciling the conflicting perceptions of efficiency and equity which underlie the wheeling debate will be a major challenge to legislators and regulators as they attempt to structure a "level playing field”for competi- tion to evolve in the years ahead. AUTHOR'S NOTE:This article was completed prior to the submission of comments in response to Phase 1 of the Federal Energy Regulatory Commission's Notice of Inquiry (Docket No.RM85-17)addressing numerous aspects of the transmission access and pricing issue.The extensive comments,filed by over 120 parties represent- ing all perspectives in the wheeling debate,provide the most comprehensive source of information currently available on the issues discussed in this article. Regulator Proposes Electricity Buyers'Cooperatives Illinois Commerce Commission Chairman Philip R.O'Connor has urged industrial users of electricity to think seriously about joining together to form energy cooperatives in order to lower their energy costs.Speaking to a meeting of the Electric Consumers Resource Council in Washington,D.C.,recently O'Connor compared elec- tricity consumer cooperatives to farmer cooperatives that developed during the late 19th century,which allowed farmers to buy commodities and services in greater quantities,providing them greater market power than they had as individuals.He suggested that industrial consumers think in the same terms and look for opportunities to lower their electric costs through joint purchases of electricity and joint ventures.But he added that cooperative ventures will serve little purpose if utilities are not required to wheel electricity for municipal utilities,public power agencies,and industrial customers. OCTOBER 31,1985-PUBLIC UTILITIES FORTNIGHTLY 33 'his {o AI0OC Minutes November 13,1985 Page 5 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,JANUARY 15,1986 BEGIN at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda II.Committee correspondence and reports A.SCADA/METERING/COMMUNICATIONS -menetes statedB. Dispatch/Scheduling Subcommittee weac #4 Carvery requitaatsC.Intertie Status Update (A.P.A.) D.Proposed Operating Committee Manuals Updating IV.Visitor comments related to items on agenda V.Old Business VI.New Business . SeSSt ENA.Recess and work stetterr B.SCADA/METERING/COMMUNICATIONS C.Dispatch/Scheduling D.Intertie Operating Committee Manuals consolidationE.University of Alaska,Fairbanks-Dynamic Stability Study F.Others VII.Formal Operating Committee action/recommendation VITI.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeti -2286/521/5 Senet -- ng location:Chugach Electric Association Operations Training Room 5601 Minnesota Drive Anchorage,Alaska 99502-0300 (907)563-7494 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA- WEDNESDAY,MARCH 19,1986 (Revised Date) BEGIN at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports Dispatcher/Training Dispatch/Scheduling Subcommittee Intertie Status Update (A.P.A.) Proposed Operating Committee Manuals UpdatingVAWY IV.Visitor comments related to items on agenda V.Old Business VI.New Business Recess and work station Dispatcher/Training Dispatch/Scheduling -Intertie Operating Committee Manuals consolidation -Election of Officers .OthersYHoOQwWLY VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light &Power Main Conference Room 1200 East First Avenue Anchorage,AK 99501 (907)279-7671