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Anc Fairbanks Intertie Committe Operating Minutes 1985
Record Copy File #iWE PES 27d ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,NOVEMBER 13,1985(AT FAIRBANKS MUNICIPAL UTILITIES SYSTEMS) Attendance: James Hall Matanuska Electric Association John C.Marshall Chugach Electric Association Bradley Evans Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Mike Massin Anchorage Municipal Light and Power Hank Nikkels Anchorage Municipal Light and Power Afzal H.Khan Alaska Power Authority Alan W.Martin Fairbanks Municipal Utilities System Sam Mathews Homer Electric Association,Inc. Dave Barden Homer Electric Association,Inc. David Spell University of Alaska,Fairbanks Bob Merritt University of Alaska,Fairbanks John Aspnes University of Alaska,Fairbanks Laurie Oppel University of Alaska,Fairbanks George Mulligan University of Alaska,Fairbanks The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Fairbanks Municipal Utilities Systems Board Room. John Marshall motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unanimously. Bob Orr then motioned for the agenda to be adopted as written.Mike Massin seconded the motion and it was adopted unanimously. Under Committee's Correspondence and.Reports,the Committee received no correspondence since the last meeting. Bob Orr discussed the minutes of the meeting held by SCADA/METERING/COM- MUNICATIONS Subcommittee.The meeting was held on November 12,1985 at9:00 a.m.at the Golden Valley Electric Association Training Room.(Bob Orr also furnished the Operating Committee with a set of minutes whichareattached).It has been brought to the Alaska Power Authority's attention that the Utilities need the copies of the current transformer curves and test reports.Mike Massin commended the SCADA subcommittee for the accomplishments on SCADA/METERING/COMMUNICATIONS. Marvin Riddle discussed the minutes of the meeting held by the Dispatch Scheduling Subcommittee.This meeting was held on November 12,1985 at 1:00 p.m.at the Golden Valley Electric Association Training Room. 2286/521/1 "current. AIOC Minutes November 13,1985 Page 2 Afzal Khan from the Alaska Power Authority has informed the Operating Committee that the Alaska Intertie Agreement is ready for the UtilitiesGeneralManagers'signature.Also,Afzal Khan indicated that the Maintenance Agreement has been finalized and will be available to the Utilities for review and comments.The Transmission Line Agreement with MEA is ready for MEA's comments.Bob Orr discussed the contents of the letter which he addressed to Dave Eberle.The items discussed concerns the Static Var System.Afzal Khan noted that most of the items listed are of minor nature and will not hinder transferring power over the transmission line. There were no visitors present at the meeting. The Operating Committee had no old business to conduct at the meeting. Under New Business,Chairman Mike Massin requested Dr.John Aspnes,Head Electrical Engineering Department,University of Alaska,Fairbanks,to give a report on the Dynamics Stability Study and System Analysis and Database Management.Dr.John Aspnes thanked the Operating Committee for providing the financial support.He submitted the final report and discussed the contents of the report.Also,he gave a slide presenta-tion.He noted that the University has developed the data base and ishopingtodofurtherwork.Dr.John Aspnes informed the Operating Committee that he did not come up with a proposal for extra work. Bob Orr noted that from the operational point of view that some of the results are alarming.Mike Massin suggested to Dr.John Aspnes that he come to the next meeting to discuss the System Analysis and Database Management.Dr.John Aspnes noted that two years ago it was a good idea to do analysis of the Anchorage-Fairbanks Interconnected Power Systemsandhehopedthistocontinue.Or.John Aspnes informed the Operating Committee that the useful data has been collected for the utilities.He informed the Operating Committee that the database is accessible to the utilities.Th bMerrA ting rometheUniversi ty-of-Alaskay;Fairbanks ,discussed the fgeomagnetically..rrentsand.solar activity:indetail.Dave Spell atso from the University of Alaska,Fairbanks,gave a slide presentation on computer based instrumentation development. The Operating Committee recessed into a lunch break from 12:00 noon to 1:35 p.m. The Operating Committee then went into the work session discussing the Operating Committee manual consglidation..Mike-Massin.suggested that he-Will-work.with Afzal Khan”in bringing the Operating.Comnittee,Manuals Turning to SCADA/METERING/COMMUNICATIONS Subcommittee,Bob Orr suggested that the Operating Committee members should carefully look into the eight items which he listed in the SCADA Subcommittee minutes. The Operating Committee indicated that it has no objections to the changes made to the Alaska Intertie Transaction Form and Alaska Intertie 2286/521/2 AIOC Minutes November 13,1955 Page 3 Operations Hourly Data and Summary sheet by the Dispatch/Scheduling Subcommittee. 'Mike Massin and"Afzal Khan"will”look into”the -Intertie OperatingCommitteeManualtonsolidattonsntatmo Mike Massin suggested that the Operating Committee members should go over in detail and be able to discuss the final report prepared by the University of Alaska,Fairbanks,at the next meeting. The Operating Committee agreed with Mike Massin that a letter be sent to Dan Rice thanking him for the Alaska Intertie plaque.The Operating Committee members agreed that a letter be sent to R.E.Etheridge, Associate Executive Director,Alaska Power Authority,requesting him to<designate an engineer or ee fa}Po UIMe Dass ta”Coord I hate the'work=wi th'the uttlities,Also,the Operating Committee members agreed that aletterbesenttoDaveEberle,Project Manager,Alaska Power Authority, regarding miscellaneous design/construction deficiencies. Under formal Operating Committee action/recommendation,Marvin Riddle motioned for the adoption of Operating Guide No.6,Voltage and Reactor Control.John Marshall seconded the motion.The motion was adopted uhanimously. Marvin Riddle motioned to adopt the Anchorage-Fairbanks Intertie Operat- ing Guide No.3,Scheduled Interchange.Mike Massin seconded the motion.The motion was adopted unanimously. Turning to subcommittee assignments,Chairman Mike Massin then directed the SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE TO MEET ON TUESDAY, JANUARY 14,1986 AT 9:00 A.M.AT THE CHUGACH ELECTRIC ASSOCIATION ENGINEERING CONFERENCE ROOM for the purpose of status update on data link,and finalize metering and testing standards. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET ON TUESDAY,JANUARY 14,1986 at 1:00 P.M.AT THE CHUGACH ELEC-TRIC ASSOCIATION ENGINEERING CONFERENCE ROOM for the purpose of review-ing the NERC Guide No.9. Chairman Mike Massin directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET ON THURSDAY,DECEMBER 5,1985 AT 9:00 A.M.IN THE MAIN CONFERENCE ROOM OF MUNICIPAL LIGHT AND POWER for the enhancement of the Alaska Intertie Schedule. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. 2286/521/3 AIOC Minutes November 13,1985 Page 4 THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,JANUARY 15,1986 AT 9:00 A.M.IN THE TRAINING ROOM OF CHUGACH ELECTRIC ASSOCIATION AT 5601 MINNESOTA DRIVE, ANCHORAGE,ALASKA. Alan Martin motioned for the meeting to adjourn.John Marshall seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 3:15 p.m. Respectfully submitted, bifpeH.bon Afzal H.Khan -Secretary Alaska Intertie Operating Committee Attachments:anWwNoreJanuary meeting agenda Minutes from November 12,1985 SCADA/METERING/COMMUNICATIONS Subcommittee Meeting Minutes from November 12,1985 DISPATCH/SCHEDULING Subcommittee Meeting Alaska Intertie Operating Guide No.3,Scheduled Interchange Alaska Intertie Operating Guide No.6,Voltage and Reactor Control Suggestions for Extra work -prepared by University of Alaska, Fairbanks , 2286/521/4 AIOC 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 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 SCADA/METERING/COMMUNICATIONS . Dispatch/Scheduling Intertie Operating Committee Manuals consolidation University of Alaska,Fairbanks-Dynamic Stability Study OthersAMmMIDUABDYeoeeeo.VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Chugach Electric Association Operations Training Room 5601 Minnesota Drive Anchorage,Alaska 99502-0300 (907)563-7494 2286/521/5 MINUTES SCADA/Metering/Communications Subcommittee Date:11-12-85 Time:9:00 a.m. Place:Golden Valley Electric Present James Hall MEA Bob Day AMLE&P Ray L.Duncan CEA Henri Dale GVEA Vance Cordell CEA Dan Rogers -CEA Alan Martin FMUS John Cooley AML&P Robert Orr GVEA Marvin Riddle GVEA No Pulse Counter at Douglas Ray Duncan of CEA brought up lack of a pulse counter at Douglas. All utilities expressed concern.Jim Hall of MEA agreed to look at and repair Douglas pulse counter. Data Link Update Functional testing was completed and signed off by GVEA &AML&P as far as functional specifications. The utilities will meet today to exchange lists as to definition and point availability for the data base lists. Bob Day of AML&P requested that CEA verify their configuration. Vance Cordell of CEA stated there would be a dual ported system with one port to GVEA,one port to AML&P.CEA still waiting for okay from APA to proceed with their contract for data link development which will adversely affect their completion schedule if not signed soon. Metering Requirements Bob Orr stated each utility was supposed to review the 11 metering points that we previously discussed. Standards for Revenue Metering,Sealings,Testing 1)Testing interval a)Test on annual basis in month of June,starting June 1986. b)Any unscheduled meter testing shall be approved by the Operating Committe. SCADA/Metering t ites Page 2 2)Sealing -no special sealing required. 3)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. 4)Calibration The standard for meter testing shall be calibrated and shall be traceable to Bureau of Standards.Must be capable of 1% accuracy.The meter standard to be used for testing will have to have been calibrated in the last 5 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 valves and results is to be recorded and submitted to the participants and the SCADA/Metering Subcommittee.The test report shall also show Standards used,personnel present,and date standard and meter was tested.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. 5)Cr/PprT accuracy--ratio testing 6) 7) 8) No CT/PT accuracy testing is anticipated unless requested by SCADA/Metering Subcommittee and approved by Operating Committee. Remote versus Local accuracyFieldcheckpulseaccumulators 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 3 days after the end of the month. 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: a.Instant versus pulse counter versus register,monthly reading accuracy. b.Comparison of register readings to remote pulse counter accuracy. 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 SCADA/Metering !ites Page 3 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. This draft will be reviewed by the Subcommittee and finalized at the next meeting. Robert Orr Chairman MINUTES Dispatch Scheduling Subcommittee Date:11-12-85 Time:1300 hours Place:Golden Valley Electric The meeting was called to order at 1300 hours.ThoSe present were: Ray Duncan CEA Marvin Riddle GVEA John Cooley AML&P Dave Barden AEGT The following discussion occurred: 3Operatingguide#€should be modified to read: Section II (B)"The ramp will start at 5 minutes before and end at 5 minutes after the hour.This ramp will be equally divided across the 10 minute time frame." Dispatcher will reconcile Alaska Intertie Transaction Sheet and Alaska Intertie Operations Hourly Data &Summary Sheet. Subcommittee recommends Guide #6 be adopted.Subcommittee will review Guide #9 in relation to Intertie contract. The Dispatch Scheduling Subcommittee recommends that starting December 1,1985 at 0001 hours the following changes be made in compiling the Alaska Intertie Operation Data.Healy,Douglas,and Cantwell meters will be read to one decimal,calculated midpoint and round to nearest MW (i.e.0.5 is rounded up to 0.4 and less is rounded down).This will effectively show midpoint and inadvertently in even MW's.Recommend we try this for 30 days and review. Spot checking November readings by rounding these readings.It is approximately .3%difference by not rounding.We don't feel this is traceable. Once all pulse accumulators are in service,this will reconcile. ' cvin Riddle hairman Anchorage-Fairbanks Intertie OPERATING GUIDE NO.3 SCHEDULED INTERCHANGE Coordination of scheduled interchange between control areas is essential for proper frequency control,to minimize inadvertent power flow,and to prevent exceeding normal transfer limits. When formulating and executing schedules,the following is recommended: I.SCHEDULED POWER LIMITATIONS A.The new amount of power scheduled between control areas should not exceed the mutually established transfer limits of the common interconnections and alternate paths which have been arranged for between'the parties.When establishing normal and emergency transfer limits, consideration should be given to the effect of power flow through their own and other parallel systems or control areas based on mutually acceptable reliability criteria. In no case should the scheduled power flow exceed the total capacity of available transmission facilities between the two control areas owned by them or available to them under arrangements or contracts.Power should only be scheduled between control areas having direct connecting facilities in service unless there is specific agreement with the control areas which provide the connecting facilities. B.When transmission facilities are out of service,either -internal to a control area or between control areas,normal transfer limits should be reevaluated and schedules adjusted as appropriate.In case of an unscheduled outage, such adjustments should be made as soon as practicable. II.SCHEDULE CHANGES BETWEEN CONTROL AREAS A.Schedule changes shall be made at a uniform rate agreeable to both the supplier and receiver.Supplier and receiver should agree on the starting time for a scheduled change. B.The ramp will start at 5 minutes before the hour and end at 5 minutes after the hour.This ramp will be equally divided across the 10 minute time frame.The rate of change for schedules should be limited by the ability of the parties to effect the change;provided,however,that such changes do not burden any other system. C.When area control equipment additions and modifications are to be made,consideration should be given to the existing or Planned equipment in adjacent control areas for compatability in coordinating scheduled interchange. Revised: Approved: ALASKA INTERTIE Operating Guide No.6 Voltage and Reactive Control The system operator must keep capacitive and inductive reactive resources in proper balance to maintain voltages within acceptable limits,minimize real power losses,and minimize interference to interconnected utilities. The following guidelines will aid the system operator in maintaining the proper balance of reactive resources: I.OPERATIONAL PLANNING A.Each system should provide for its own internal transmission and load reactive requirements,as well as its share of reactive requirements associated with interconnecting transmission lines and imported and exported power. B.The system operartor should be aware of all generation and transmission reactive resources available for his use. C.The system operator should be aware of reactive limits and -allowable voltage deviations throughout his system. D.Sufficient data acquisition equipment,with suitable visual and/or audible indicators,should be available to the system Operator to monitor system voltage levels,LTC settings, reactive flow,and Status of rotating and static transmission reactive resources. E.System operators should be aware of and authorized to use corrective action,including load reduction,necessary to prevent voltage collapse when reactive resources are insufficient. F.Power flow and stability studies should be conducted to determine additional reactive requirements resulting from reasonable generation and transmission contingencies. G.Prearranged voltage levels,reactive control equipment settings,and changes in transmission line configuration should be coordinated with neighboring systems to prevent detrimental reactive flow. H.Transfer or interchange limits should reflect voltage or reactive restrictions in addition to thermal and stability limitations. Revised: Approved: Il. III. -2- Reactive resources should be planned so that the system Operator can maintain scheduled voltages for all normal and first contingency operations. All reasonable efforts should be made to keep major transmission lines in service during light load periods. Major transmission lines should be removed from service for voltage control only after all reactive control is fully utilized and appropriate studies indicate that system reliability will not be degraded below acceptable levels. Voltage reduction to obtain load relief should only be only be implemented on the sub-transmission and distribution systems. ON-LINE OPERATIONS A.Automatic voltage regulators and power system stabilizers should be kept in service on generating units.and synchronous condensers,to the maximum extent possible, in order to insure stability and proper voltage response to abrupt changes in generation and transmission. System operators should systematically monitor the system for deviations from prearranged voltage levels and anticipated reactive flow and take corrective action when necessary. Corrective action should not impose unacceptable voltage stress on internal generation or transmission equipment, reduce system reliability beyond acceptable limits,or unduly impose voltage or reactive burdens on neighboring systems.Corrective action may require load reduction in order to stay within the stated limits. Neighboring systems should be notified when taking any action that would significantly affect the voltage or reactive flow in their system. OPERATIONAL REVIEW A.Surveys should be made periodically and during abnormal operations and analyzed for compliance to voltage and reactive guidelines. Periodic review should be made with planning engineers to insure that long'range planning allows operational compliance with the voltage and reactive guidelines. Revised: Approved: Specific stability program features that were not included and should be available are:(1)a SVS model built into the program; and (2)reactance,under/over voltage,reverse power,directional, phase and ground overcurrent,and differential relay models. Adding these SVS and relay modules would greatly enhance program versatility and convenience,ease and speed of system simulations. 5.3 Suggestions for Further Work 5.3.1 Data base maintenance and improvement This project has provided an excellent first step in creating a comprehensive data base describing the Anchorage-Fairbanks interconnected power systems.This data base is a key element of the project and this report and proved extremely time-consuming to build.It will be time-consuming to maintain and improve,but these activities are essential to future system studies.The interconnected power system will always be changing and the present data base is almost certainly incomplete although it was carefully prepared from the best and most up-to-date information available. It is hoped that the railbelt utilities will continue to provide data and support for data base management. 5.3.2 Load retention studies In reviewing the stability cases presented in this report,it appears that further investigation of load retention plans may be appropriate,particularly with respect to system dynamic response to faults. 5.3.3 Optimum power flows Determining optimum power flow for a variety of overall interconnected system conditions should be an economically attractive project.The objective would be to minimize overall -87- system losses and var requirements while maintaining acceptable bus voltage levels. 5.3.4 Intertie rating It would be helpful to system operation if intertie ratings were accurately known with respect to temperature,voltage drop, steady-state stability and transient stability.This information would allow operation closer to actual limits. 5.3.5 Relation of spinning reserve and stability Dependence of stability on spinning reserve may be an important issue. 5.3.6 Static wire insulator deterioration Static wire insulator degradation has been recently observed along the intertie.An analysis of and solution to this problem may be possible using the Electromagnetic Transients Program (EMTP).A working copy resides on the UACN VAX 11/785 computer. 5.3.7 Long range planning Data base and program development for generation planning, Toss of load probability and financial simulation are all areas that could provide economically beneficial results for all interconnected utilities.. 5.3.8 System load modeling Constant impedance loads have been assumed in this and previous system studies.Accuracy of future analyses could be improved by more detailed load models. -88- 5.3.9 Continuing GIC analysis Instrumentation development and installation for analysis of geomagnetically induced current (GIC)in the intertie have been funded by the Alaska Power Authority.Additional support is required for data collection and analysis. -89- oho LEG,MAESWoh+Kher Yo - November 4,1985 bee fr 80 Mr.Robert Martin,Jr. General Nanager Chugach Electric Association,Inc. Pouch 6300 Anchorage,Alaska 99502-0300 Dear Bob: Mr.Tom Martin has informed the Power Authority that a statement was required on the source of funding for the Alaska Intertie before ChugachElectricAssociation(CEA)will execute the Intertie Agreements.My intent in this letter is to satisfy that requirement and to give CEA their requested assurance. The Alaska Intertie was funded as follows: S.L.A. Appropriation #Year Amount Chapter 50 1980 §$3,000,060 Chapter 52 1981 36 ,900 ,000 Chapter 92 1981 40 ,GOO ,Goo* Chapter 107 1983 25 ,000 ,000 Chapter 171.1984 18 ,660 ,GO0 TOTAL $122 ,600 ,000 *Available for Fiscal Year 1982. It has been constructed for $122.6 million and is nearing commercial operation,The total capital cost of the Alaska Intertie has been funded by the grant appropriations and will not be recovered in any rates or charges for use of the Intertie.The project cost includes thesettlementwiththeAhtnaCorporationfortheuseofthetrlandsand rights to access over their lands. Article 8 of the Alaska Intertie Agreement provides that the Annual Debt Service on bonds or any other debt by APA for the initial Intertie facilities shall be shared by the Utility participants.The Authority has not {issued bonds or other debt for the Intertie and does not contemplate doing so.Other costs incurred as enumerated in Article 8 will be paid by Utility Participants. 1§87/478/1 raye c I trust that this letter is sufficient for your purposes and invite your questions and comments if it is not sufficient. Sincerely, a,Nf . Robert D.Heath Executive Director EM/RDH/tg cc:Michael Kelly,Golden Valley Electric Association,Fairbanks James F.Palin,Hatanuska Electric Assoctation,Palmer Virgil Gillespte,Fairbanks Municipal Utility System,Fairbanks Thomas Stahr,Anchorage Huncipal Light &Power,Anchorage Kent Wick,Homer Electrical Association,Homer Tom Martin,Chugach Electric Association Margie MacNeille,Chugach Electric Assoctfation Mike Massin,Anchorage Municipal Light &Power,Anchorage Sam Mathews,Homer Electric Association,Homer Ken Ritchey,Matanuska Electric Association,Palmer John Marshall,Chugach Electric Association,Anchorage -. Larry Colp,Fairbanks Municipal Utility System,Fairbanks Robert Orr,Golden Valley Electric Association,Fairbanks Everett Diener,City of Seward,Seward Bob Cross,Alaska Power Administration,Juneau bec:Ed Morris,Alaska Power Authority Glooia Manni,Alaska Power AuthorityRE,Esher tase Alaska Power Authority|Ps u/s 1§87/478/2 .MEMORANDUM TO:Bill Sobolesky DATE:November 1,1985 Accountant /O&M/Intertie We ;FROM:Harry Beck SUBJECT:Operations &Maintenance Operations Engineer Interim Rate Summary a OPERATIONS &MAINTENANCE DIRECTORATE INTERIM RATE SUMMARY PROJECT |FY85 TOTAL PROJECTED FY86 --USEAGE (KWH)!0 &M COSTS? SOLOMON GULCH 34,322,890 $539,024 TERROR LAKE 58,500,000 $1,019,756 SUAN LAKE 46,655,000 $561,827 TYEE 25,716,610 $1,320,359 "TOTALS 165,194,500 $3,440,966 'From actual billing statements 2 From Operations &Maintenance Directorate 1986 Budget Worksheet Summary Revision 3 cuee *..Estimated O &M COMPONENT =$3,440,966 X 100 ¢/$=2.08 ¢/KUH 165,194,500 KWH DEBT SERVICE COMPONENT =2.64 ¢/KWH TOTAL =4.72 ¢/KWH SUGGESTED INTERIM RATE..«.ee-4.72.¢/KWH z:ry.Wolf,Alaska Power AuthorityardThackesAlaskaPowerAuthority Municipal Light &Power *Since 19321200EASTFIRSTAVENUE-ANCHORAGE,ALASKA 99501-1685 et TELEPHONE (907)279-7671 - Tony Knowles. Mayor October 14,1985 Mr.Robert D.Heath Executive Director Alaska Power Authority 334 West Fifth Avenue Anchorage,Alaska 99501 Dear Mr.Heaths: Here is a fully executed copy of the Letter of Non-Objection,Alaska Intertie Limited Operation.I have also enclosed,for your information,a copy of the Memorandum of Understanding between ML&P and GVEA which provides for economy sales of energy over the Intertie. Sincerely, A ES Thomas R.Stahr General Manager Municipal Light &Power slg encls/2 PROVIDE FOR TOMORROW,SAVE ENERGY TODAY. ALASKA POWER AUTHORITY 334 WEST 5th AVENUE -ANCHORAGE,ALASKA 99501 Phone:(907)276-0001 October 4,1985 Mr.Thomas Stahr General Manager Anchorage Municipal Light and Power 1200 East First Avenue Anchorage,Alaska 99501 SUBJECT:Alaska Intertie Limited Operation Letter of Non-Objection Dear Mr.Stahr: Golden Valley Electric Association (GVEA)and Municipal Light &Power (ML&P),("the Utilities")have requested authorization to energize and transfer approximately 15MW through the Alaska Intertie Transmission Line prior to execution of the "Intertie Agreement"or "Testing Agreement".This letter constitutes notice of Alaska Power Authority's non-objection to such utilization provided that GVEA and ML&P agrees to the following provisions governing such utilization: 1.GVEA and ML&P will be responsible for and direct all such operation in a safe manner so as to comply with the NESC and other safety standards. 2.Utilities will pay all direct or indirect costs of such operation. 3.APA assumes no liability directly or indirectly from such action and GVEA and ML&P agrees to defend,indemnify,save and hold APA harmless from all claims related to such operation. APA,however,shall not hold utilities liable for failure or damage of the transmission line or substations,except to the extent that such failure or damage results from their actions. 4,Utilities will maintain insurance covering intended operation and employees involved with limits and coverage not less than the insurance each presently maintains for its current overall operations.Such insurance shall name the APA as an additional insured. 5.APA offers no warranty of fitness of the line or substation for the intended purpose. 6.GVEA and ML&P retains any and all obligation to their consumers and agrees to inform Intertie connected utilities that service may be interrupted at any time to facilitate 1323/471 Mr.Stahr October 4,1985 Page 2 10. Intertie Testing,Start-Up or Maintenance.This agreement shall not be construed by the parties to create any legal duty on the part of APA to provide or maintain continuity of service to utilities or consumers. This non-objection may be terminated by APA at any time for just cause. This non-objection shall expire upon the effective date of a formal "Intertie Agreement,""Testing Agreement"or on notice by either utility. GVEA and ML&P agree not to interfere either directly or indirectly with ongoing Alaska Intertie activities associated with the remaining construction,testing,operation and acceptance of the intertie electrical systems and further agree to provide proper interface and coordination with those entities now involved with work associated with the Alaska Intertie. This non-objection is subject to written indication of agreement with the terms of this letter prior to utilization. If you have any questions regarding this letter of non-objection, please contact Mr.Howard Thacke of this office. v Sincerely,le UA,Robert D.Heath Executive Director HT/RH:fs cc:David Eberle R.E.Etheridge Howard Thacke Ed Morris Afzal Khan All Utilities, See Distribution List. 1323/471 Mr.Stahr October 4,1985 Page 3 1323/471 Terms and conditions are hearby acknowledged and accepted:iil Xt Leola ysMichaelWhe°General Manager,avEA ar LOLS FS™ Tom Stahr Date General Manager,ML&P Mr.Stahr October 4,1985 Page 4 DISTRIBUTION LIST 10/4/85 Mr.Michael Kelly General Manager P.O.Box 1249 Golden Valley Electric Association Inc. Fairbanks,Alaska 99707 Mr.Robert Martin,Jr. General Manager Chugach Electric Association,Inc. P,0.Box 196300 Anchorage,Alaska 99519-6300 Mr.James F.Palin General Manager Matanuska Electric Association,Inc. P.Q.Box 1148 Palmer,Alaska 99645 Mr.Virgil Gillespie General Manager Fairbanks Municipal Utilities System P.0.Box 2215 Fairbanks,Alaska 99707 Mr.Kent Wick General Manager Homer Electric Association,Inc. P.0.Box 429 Homer,Alaska 99603 1323/471 MEMORANDUM OF UNDERSTANDING This Memorandum of Understanding is entered into between MUNICIPAL LIGHT &POWER DEPARTMENT of THE MUNICIPALITY OF ANCHORAGE ("ML&P")and GOLDEN VALLEY ELECTRIC ASSOCIATION (GVEA"). Recognizing that the Alaska Intertie currently being completed by the Alaska Power Authority will become operational for testing in the very near future,and Recognizing that it is in the public interest to facili- tate operation of the Intertie for the mutual benefit of all participants, ML&P and GVEA-agree to the following: 1.ML&P has now available,or will have available at the time that the Alaska Intertie become operational for testing,sufficient generation capacity excess to its needs at certain times to allow ML&P to make such excess energy available for sale to GVEA. 2.GVEA and ML&P agree that it is in the best interest of their consumers to utilize such energy excess to ML&P's needs to the fullest within the Railbelt because of.its cost relative to GVEA's cost of generation, 3.GVEA agrees to pay ML&P for all power delivered in an amount to be developed by the parties during negotiation of a Power Sales Agreement.In the interim,GVEA agrees to pay an amount as shown on the attached schedules.The deli- very point for such energy shall be ML&P's bus at Plant #2. PAGE 1 OF 8 acihlthintallin si Maneatiaice ea sebeahn rial Dalla abe a oe ve me 4.GVEA and ML&P agree that the rate formulas appearing in the attached Economy A and B Energy schedules shall apply to electric power delivered by ML&P to GVEA provided that GVEA pays an equivalent markup of no more than 5 mills/KWH for economy energy secured from another source.If a higher equivalent markup is paid to another source,the higher markup shall also apply to all power supplied under this Memorandum of Understanding.For the purpose of calcu- lating equivalent markup,it shall be defined as delivered cost minus 1.5 Mill/KWH variable maintenance cost minus incremental fuel'cost.Any recovery of capital costs for eco- nomy energy transfers shall be deemed to be markup. 5.GVEA and ML&P agree that this Memorandum of Understanding will allow the parties to proceed with execu- tion of transactions over the Alaska Intertie.It is the intent of the parties,however,to negotiate a full Power Sales Agreement.This document shall remain valid until replaced by a full Power Sales Agreement or cancelled by either utility upon sixty (60)days written notification of the utility. PAGE 2 OF 8 |6.ML&P AND GVEA agree that for purposes of calculating spinning reserve,economy energy interchange shall be treated as if it were generated by the purchasing party. DATED at Anchorage,Alaska,this //day of October,1985. RECOMMENDED: GOLDEN VALLEY ELECTRIC ASSOCIATION MUNICIPAL LIGHT &POWER DEPARTMENT OF THE MUNICIPKLITY OF ANCHORAGE By:WA.>By:<4 EEL.Michael Kelly - "Thomas R.StahrIts:General Santger Its:General Manager APPROVAL: MUNICIPALITY OF CHORAGE| Bob(sSmith - Its:Municipal Manager PAGE 3 OF 8 Cite callie ante ade a EMERGENCY SERVICE SCHEDULE ML&P and GVEA Conditions It is the intent of both parties that GVEA is entitled to request Emergency Service and ML&P shall be obligated to supply such Emergency Service to the maximum extent prac- ticable.At the time of any request for Emergency Service, GVEA shall provide ML&P information concerning the nature and extent of the conditions causing the emergency.When any request for Emergency Service is made and an agreement is reached as to (1)the amount of Emergency Service which can be delivered,(2)the probable duration of such delivery,(3) the schedule of delivery of such energy,(4)any necessary notice requirement for discontinuance of such delivery,and (5)any other pertinent factors,then ML&P shall furnish the requested Emergency Service from any available source to the extent that,in ML&P's judgement,the generation or purchase and delivery of such Emergency Service will not impair or jeopardize service to ML&P's system or its commitments to others. Rate &Billing Scheduled deliverance of Emergency Service shall be billed and paid monthly per the following rate: [51.31 +CGC*|29.72]Mills/KWH1.4533 *CGC =Current price of gas ($/MCF) PAGE 4 OF 8 tee ow a Oras MAINTENANCE SERVICE SCHEDULE ML&P and GVEA Conditions It is the intent of both parties that GVEA is entitled to request Maintenance Service and ML&P shall be obligated to supply such Maintenance Service to the maximum extent possible. GVEA shall give at least four (4)hours notice of its Maintenance Service Requirements.At the time of any request for Maintenance Service,GVEA shall provide ML&P information concerning the nature and extent of the con- ditions which result in the need for such service.When GVEA requests and an agreement is made as to (1)the amount of Maintenance Service which can be delivered by the seller,(2) the probable duration of such delivery,(3)the schedule of delivery of such energy,(4)any necessary notice require- ments for discontinuance of such delivery,and (5)any other pertinent factors,then ML&P shall furnish the requested Maintenance Service from any available source to the extent that,in ML&P's judgement,the generation or purchase and delivery of such Maintenance Service will not impair or jeopardize service to the sellers system or its commitments to others.If ML&P must start a generating unit to provide such power,GVEA must take the power for a minimum of 12 hours.If a unit is started and the take is 4 hours or less, the Emergency Service rate will apply. Rate &Billing Scheduled deliveries of Maintenance Service shall be billed and paid monthly per the following rate: [23.51 +/_ccc*_)\l6.9]Mills/KWH1.4533 CGc*=Current Price of Gas ($/MCF) _ndlaiadtnelllitetisnitemites.tities Rik hans L pt ShitaaiabeE vate,ce eee PAGE .5 OF 8 cee ect cea ecb ECONOMY A ENERGY SERVICE ML&P and GVEA Conditions Economy A Energy shall mean Energy on a "when,as and if" available basis from ML&P's generating resources to GVEA to reduce the output of GVEA's available generating resources. Units will not be started to provide Economy A Energy. Delivery can be terminated by ML&P at any time upon reaso- nable notice to GVEA.Upon request,ML&P may supply Economy A Energy up to the capacity of the power source or fuel available for such supply subject to the judgement of ML&P that the supply of such Energy will not impair or jeopardize service to its own customers,including other electric systems.ML&P shall be the sole judge of the capacity and fuel available for Economy A Energy supplied from its system and all commitments to other systems which may have priority over Economy Energy supplied hereunder. Rate &Billing Scheduled deliveries of Economy A Service shall be billed and paid monthly per the following rate: Units 1,2,3 [19.2/CGc*\+6.5]Mill/KWH1.62 Unit 4 [16.6 cec*|+6.5]Mill/KWH1.62 Unit 5,6,7 (15.0 cac*\+6]Mill/KWH1.62 Unit 8 (15.1/cGc*\+6]Mill/KWH(ML&P)Exclusive use)1.62 Unit 8 (Joint use with CEA)The incremental cost to ML&P of the la hai iM tt wine = load caused by GVEA plus 6 Mill/KWH. Incremental cost equals the seller's portion of the usage cost defined by ML&P/CEA Unit 8 contract minus the seller's portion if no power was taken by GVEA divided by the amount of power taken by GVEA from Unit 8. *0GC =Current Price of Gas ($/MCF) ue sun anime I a PAGE 6 OF R ECONOMY B ENERGY SCHEDULE ML&P and GVEA Conditions Economy B Energy shall mean Energy on a "when,as and if" available basis from ML&P's generating resources to GVEA to reduce the output of GVEA's available generating resources. If a unit is started to provide Economy B Energy,GVEA must take the power for a minimum of 8 hours.Delivery can be terminated by ML&P at any time upon reasonable notice to GVEA.Upon request,ML&P may supply Economy B Energy up to the capacity of the power source or fuel available for such supply subject to the judgement of ML&P that the supply of. such Energy will not impair or jeopardize service to its own customers,including other electric systems.ML&P shall be the sole judge of the capacity and fuel available for Economy B Energy supplied from its system and all commitments to other systems which may have priority over Ecomony B Energy supplied from its system and all commitments to other systems which may have priority over Economy Energy supplied hereunder. Rate &Billing Scheduled deliveries of Economy B Service shall be billed and paid monthly per the following rate which is the sum of starting charge,no-load charge and the incremental costs given in Economy A Schedule. Starting Charges No-Load Charges Unit 1,2,3 $80 (cscs) | $130/cGc*Var1.62 1.62 *CGC =Current Price of Gas ($/MCF) PAGE 7 OF 8 Starting Charges Unit 4 $240 (cec*\1.62 Unit 8 $280 (|1.62 *CGC =Current Price of Gas ($/MCF) PAGE 8 OF 8 No-Load Charges $130 cect Vr1.62 $290 /ccc*\/Hr 1.62 Record Copy File #ANT Ro 5-4 ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,October 9,1985 (At Municipal Light and Power,Anchorage) Attendance: James Hall Matanuska Electric Association John C.Marshall Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Mike Massin Anchorage Municipal Light and Power John S.Cooley Anchorage Municipal Light and Power Afzal H.Khan Alaska Power Authority Harry Beck Alaska Power Authority Larry Colp Fairbanks Municipal Utilities System Sam Mathews Homer Electric Association,Inc. Dave Barden Homer Electric Association,Inc. Lee C.Warnock ;Morrison-Knudson Company,Inc.- The meeting was called to order by Chairman Mike Massin at 9:20 a.m.in the Municipal Light and Power main conference room. Marvin Riddle motioned that the minutes be adopted as written and John Marshall seconded the motion.The motion was approved unani- mous ly. Larry Colp then motioned for the agenda to be adopted as written. Bob Orr seconded the motion and it was adopted unanimously. Under Committee's Correspondence and Reports,the Committee re- ceived no correspondence since the last meeting. Bob Orr discussed the minutes of the meeting held by SCADA/METERING/COMMUNICATIONS Subcommittee.The meeting was held on October 8,1985 at 9:00 a.m.at the Chugach Electric AssociationEngineeringRoom.(Bob Orr also furnished the Operating Committeewithasetofminuteswhichareattached). Marvin Riddle along with John Cooley provided the Operating Commit- tee a report on the Dispatch Scheduling Subcommittee meeting.This meeting was held on October 8,1985 at 1:00 p.m.at the Chugach Electric Association Engineering Room. Marvin Riddle submitted the Alaska Intertie Operating Guide No.4 and requested the Operating Committee to adopt it.John Cooley submitted the Alaska Intertie Operations Hourly Data and Summary Sheet with instructions.John Cooley also submitted the Alaska In- tertie Transaction Form and the Alaska Intertie Scheduling 9894/482 AIOC Minutes October 9,1985 Page 2 procedure.The Operating Committee then decided to review the above items during the work session. Afzal Khan from the Alaska Power Authority then discussed the items associated with power transformer at Gold Hil]Substation and modi- fications to the Static Var System at Gold Hill and Healy Sub- stations.The repaired 100MVA Gold Hill Power transformer has been installed and successfully tested by Westinghouse Electric.At present,the transformer is carrying about a 20MW load.GeneralElectric,field engineer (Don Homer),changed the starting sequence at the Gold Hill and Healy Static Var System controls.The changes reduced the harmonics and eliminated the period of reduced voltage. The voltage excursion is about one cycle according to General Elec- tric.The thyristor cells failed when the emergency shutdown was exercised.The Static Var System at Teeland Substation cannot be taken out of service due to its importance to maintain 138KV at Teeland bus.Therefore,the changes to the starting sequence of the Teeland Substation Static Var System cannot be completed by General Electric until Chugach Electric Association completes modi- fication of Teeland Substation which will be in January 1986.The raising of the low bus at Gold Hill and Healy SVS buildings will not take place until next year.The Ahtna claim came up and the operating committee was told that a settlement has been reached. Alaska Power Authority's letter of no objection to intertie use for testing was sent to General Managers of concerned utilities.The Operating Committee was told that there is going to be changes in the insurance clauses of the Alaska Intertie Agreement and Maintenance Agreement. Then Lee Warnock,Morrison-Knudson,was asked to brief the Operat- ing Committee on the remaining work left on the project.Lee Warnock,Morrison-Knudson,stated that there is a test procedure for the SVS called a "loss"test.Bob Orr,GVEA,said that he didn't know what a loss test was.He further stated that he wanted to see an acceptance test for the SVS for review.Mike Massin recommended that MK forward copies of the loss test to all of the concerned parties for review.Bob Orr recommended that MK,APA andGilbert/Commonwealth (G/C)review this loss test to ensure that it meets the requirements for the SVS as identified in the specifications.When asked about acceptance test,Lee Warnock stated that a test procedure exists for each substation and line segment.Bob Orr stated that he wanted to see an acceptance test and punch lists for the substations.Lee Warnock stated that MK owes APA a final test report.Westinghouse still has to instal] temperature probes on the SF6 breakers at all the substations.TheSF6breakersexperiencelowgaspressuretripsatextremelow temperatures.Finally,Lee Warnock thanked the participant utilities for the good team work. There were no visitors present at the meeting. 9894/482 AIOC Minutes October 9,1985 Page 3 The Operating Committee had no old business to conduct at the meet- ing. The Operating Committee recessed into a break from 10:25 a.m.to 10:40 a.m. Turning to SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE,Bob Orr in- dicated that there is not much to talk other than that which had already been submitted. A brief discussion took place on Operating Guide No.4,Time Error, Alaska Intertie Transaction,and Alaska Intertie Operations Hourly Data and Summary sheet.It is noted that the Alaska Intertie transaction form has to be filled out every day.John Cooley not- ed that the supplier and receiver have to fill the transaction form.Then John Cooley proceeded to explain the Alaska Intertie Operation Hourly Data and summary sheet which included instructions.John Cooley said the basic format works.TheOperatingCommitteecommendedthesubcommitteeforpreparingtheforms.Bob Orr asked the Operating Committee if they would like to formally adopt the forms.Mike Massin indicated that the Operating Committee wait and see if it works.Mike Massin then advised the subcommittee to proceed using it. The Operating Committee then took the issue of updating the Operat- ing Procedure Handbook.The Alaska Power Authority is looking into the purchase of a document reader which transfers the data to IBM displaywriter and stores for future updating.This is true for all other manuals. According to Harry Beck,John Aspnes will present a proposal at the next Operating Committee meeting regarding new system studies for the operation of the interconnected Anchorage-Fairbanks System. Mike Massin submitted a listing of the pages,Articles/Sections from the Alaska Intertie Agreement,and brief description of the areas which involve the Operating Committee.The list is attached to these minutes. Larry Colp from Fairbanks Municipal Utilities System asked the Op- erating Committee to see if it is possible to have teleconference so frequent cost of travel to Anchorage can be avoided.The Operating Committee felt uncomfortable with the idea.After a brief discussion on this subject,Bob Orr motioned to rotate the Operating Committee meeting location starting November 1985 accord- ing to the participant list.Mike Massin seconded the motion.The motion was adopted unanimously. Sam Mathews motioned for the adoption of Operating Guide No.4,Time Error.Jim Hall seconded the motion.The motion was adopted unanimously. 9894/482 AIOC Minutes October 9,1985 Page 4 Marvin Riddle motioned to adopt the Alaska Intertie Operations Hourly Data and Summary sheet for the interim/test period for the area controllers to use.The motion was adopted unanimously. The Operating Committee proceeded to revise the list of Operating Committee designees and the alternates.The Operating Committee also revised the subcommittees designees who will serve on the sub- committees.Attached to these minutes is revised list.Bob Orr motioned to adopt the designated participants.Mike Massin second- ed the motion.The motion was carried unanimously. The Operating Committee decided to continue to meet at least once a month during this period. Homer Electric Association (HEA)and MEA will no longer be recog- nized as members of the Committee.Their representatives will now be treated as members of the Alaska Electric Generation &Trans- mission Cooperative (AEG&T),the recognized participant as iden- tified in the Alaska Intertie Agreement. G/C has informed the Committee that Dan Rice is no longer with G/C and should therefore not be consulted in any way as a part of G/C obligations to the Committee or to the Intertie project. Turning to subcommittee assignments,Chairman Mike Massin then di- rected the SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE TO MEET ON TUESDAY,NOVEMBER 12,1985 AT 9:00 A.M.AT THE GOLDEN VALLEY ELEC- TRIC ASSOCIATION TRAINING ROOM for the purpose of status update on data link,complete metering,testing,calibration,recommendation and standards. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM- MITTEE TO MEET ON TUESDAY,NOVEMBER 12,1985 at 1:00 P.M.AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION TRAINING ROOM for the purpose of looking at the NERC Guide,on the section pertinent to the Subcom- mittee,and reviewing the remaining guide. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERAT- ING COMMITTEE WILL BE ON WEDNESDAY,NOVEMBER 13,1985 at 9:00 A.M. IN THE BOARD ROOM OF FAIRBANKS MUNICIPAL UTILITIES SYSTEM AT 645 5TH AVENUE,FAIRBANKS,ALASKA. 9894/482 AIOC Minutes October 9,1985 Page 5 Larry Colp motioned for the meeting to adjourn.John Marshall sec-onded the motion.The Operating Committee then unanimously ap- proved the motion to adjourn at 1:50 p.m. Respectively submitted,Mo Cham Afzal H.Khan -Secretary Alaska Intertie Operating Committee Attachments: 1.November meeting Agenda. 2.Minutes from October 8,1985 SCADA/METERING/COMMUNICATIONS Subcommittee meeting. 3.Alaska Intertie Operating Guide No.4 Time Error. 4.The Alaska Intertie Operations Hourly Data and Summary Sheet. 5.Instructions for using the Alaska Intertie Operations Hourly Data and Summary Sheet.; 6.Alaska Intertie Scheduling Procedure 7.Alaska Intertie Transaction Form. 8.Alaska Intertie Operating Committee Designated Representatives and Alternates. 9.Alaska Intertie Operating Committee -Subcommittees. 10.Alaska Intertie Project,Contract Agreement,Operating Committee Duties and Responsibilities per 8-15-85 draft. 9894/482 Ill. IV. VI. VII. VIII. IX. ALASKA INTERTIE OPERATING COMMITTEE -AGENDA - WEDNESDAY,NOVEMBER 13,1985 BEGIN AT 9:00 A.M. Adoption of prior meeting minutes Approval/modification of agenda Committee correspondence and reports A.SCADA/Metering/Communications Subcommittee 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 Recess and work session SCADA/Metering/Communications Dispatch/Scheduling Intertie Operating Committee Manuals consolidation University of Alaska,Fairbanks-Dynamic Stability Study OthersMAMIOIODYo8©e©@Formal Operating Committee action/recommendation Subcommittee assignments Adjournment Adjourn by 3:30 p.m. Meeti ng location:Fairbanks Municipal Utilities Systems Board Room . 645 5th Avenue Fairbanks,Alaska (907)456-1000 9894/482/6 MINUTES SCADA/Metering/Communications Subcommittee Date:10-8-85 Time:9:00 A.M. Place:Chugach Electric Present Marvin Riddle GVEA | Doug Hall AML&P Dan Rogers CEA John Cooley AML&P Afzal Khan APA James Hall MEA Robert Day AML&P Vance Cordell CEA Robert Orr GVEA Ray Duncan.CEA Bob Day of AML&P -SCI/L&G are working to de-bug software on data link and to date have transferred scratch pad to Anchorage and Fairbanks.Have successfully transferred integer and decimals. Bob Orr of GVEA asked;once testing is complete,how long will ittakeAML&P to implement their packets? Bob Day of AML&P advised that it would be a few days but it will depend on how many of the lists are to be implemented now. Formal testing between GVEA and AML&P will probably commence 10-8-85 and continue through Friday,10-11-85.Testing seems to be going quite well. Dispatching should probably look at the lists of the functional requirements for data link developed in 1984 and decide what packet data is available on the north and south,and determine priority for information which is available and implement. CEA is in the progress of negotiating a contract with APA _toimplementtheCEA/AML&P data link.Schedule for software development is due to be 8-23-86 for completion. 'AML&P and GVEA reported that DECNET doesn't appear to be a significant problem in the CPU loading. CEA is working to complete RTU installation by the end of November for all essential information. CEA communication console is in the process of being installed at Dispatch. SCADA/Metering Minutes Page 2 APA has asked AML&P for proposal to provide data link/CRT to APA for viewing of the Alaska Intertie. Metering Set standards for revenue metering. Bob Orr stated he had checked the Intertie contracts and NERC for metering standards and has been unable to locate anything other than annual testing and accuracy. CEA was asked if they had any written standards.Ray Duncan said no,but he could check with Bonneville Power Administration to see if they have any written standards. Bob Orr asked about the translation for the bubble memory.APA stated they are shipping the translator to GVEA. Bob Orr stated all subcommittee members should review the 11 points stated for revenue metering with their in-house staff te=-=dsetermine trem and be prepared to finalize these standards by the next subcommittee meeting. Chairman ALASKA INTERTIB 2 2 22 020°2.2...,.°°7" OPERATING GUIDE NO.4 TIME ERROR Frequency is maintained as near 60 HZ as is practicable.However, it is impossible for a power system to match instantaneous changes in load with changes in generation.This difference between load and generation results in frequency deviations from 60 HZ,and the integrated deviation appears as a departure from correct time, i.e.,aS a time error.Standards of allowable time error have been established (see Appendix A).The following procedures are recommended for use (alone or to supplement any automatic time error control)to maintain these standards and to assure an average frequency of 60 HZ. I.TIME ERROR CORRECTION PROCEDURES A.In each interconnected area an Interconnection Monitor Shall be designated to monitor time error,and.shall initiate or terminate corrective action when time error reaches predetermined limits as shown in Appendix A.IneachRegion,a Regional Monitor shall be designated through which time error correction notifications originating with the Area Monitor will be routed to each system in the Region via established Time Notification Channels.Each control area shall take corrective action while the time error correction is in effect by applying frequency offset (or the equivalent in the direction to reduce time error.Time error correction notifications shall be serialized alphabetically on a monthly basis. B.The Interconnection Monitor shall issue a notification of time error within 0.1 second to the Regional Monitors ona periodic basis as required to assure uniform calibration of time standards.Using the Time Notification Channels, the Regional Monitors shall,each hour,on the hour, notify all systems within their respective Regions of the accumulated time error within 0.1 second.Time error notification shall be accompanied by the alphabetic designator if a time error correction is in progress. C.A time error correction shall start and terminate on the hour or half hour,and notice shall be initiated at least twenty minutes before the time error correction is to start or stop. D.An appropriate offset for time error correction shall be applied as follows: 1)The frequency schedule may be offset by 0.02 4H2, leaving the bias setting normal,or Page 2 If. 2)If control frequency cannot be offset,the Net Interchange schedule (MW)may be offset by an amount equal to the computed bias contribution during a 0.02 HZ frequency deviation (20 percent of bias). E.Based upon an agreed set of procedures,the systems of an interconnection may implement automatic time error control as a part of their automatic generation control scheme.When automatic time error correction is implemented in an interconnection,all systems in that interconnection should participate in order to avoid excessive inadvertenet energy transfers.Although such control may be expected to reduce the number of time corrections initiated by the Interconnection Monitor,it can be expected to eliminate them.Systems with automatic time error control should suspend such control whenever an announced time correction is in progress. CALIBRATION OF FREQENCY RECORDERS AND TIME ERROR DEVICES The satisfactory operation of tthe interconnected systems is dependent,in part,upon accurate frequency transducers'and recorders and time error devices associated with automatic generation control (AGC)equipment. To assist in maintaining accurate frequency and time error devices frequent calibration checks shall be made against a ,common reference source. A.In order to calibrate frequency devices,a periodic check shall be made weekly,or more frequently at the discretion of the regions or systems.The Interconnection Monitor will pass,through established Time Notification Channels, the average frequency recorded on its frequency device during a selected ten-minute period.The frequency devices associated with AGC equipment in all control areas shall be adjusted to agree with this reference. B.In order to calibrate time error devices,the Interconnection Monitor,as assigned by the Operating Committee (CEA initially),will pass to those control areas having time error recorders or automatic time error correction equipment the accumulated time error recorded by its instrument as of the beginning of the ten-minute period referred to in II-A above.The time error devices in all control areasa shall be adjusted to agree with this reference. C.Some time error devices are capable of automatic for leap-second corrections in standard time as broadcast by the National Bureau of Standards.Systems using a time error device which is not capable of automatic adjustment should arrange to receive advance notice of the leap-second and make the necessary manual adjustment in a that will not introduce a disturbance into their control system. Page 3 IIl.CONNECTION OF A SEPARATE SYSTEM OR CONTROL AREA When a control area Or areas containing time error devices have been separated from the interconnected area,upon interconnection they should calibrate their time error devices to coincide with the interconnected area by one of the following methods: A.Before connection,the separated area may institute a Time Error Correction Procedure to correct its accumulated time error to coincide with the indicated time error of the Interconnection Monitor,or B.After interconnection,the time error devices of the previously separated area may be recalibrated to coincide with the indicated time error of the Interconnected Monitor.A notification of adjusted time error shall be passed through Time Notification Channels as_soon as possible after interconnection. TIME CORRECTION SLOW FAST OPERATING GUIDE NO.4 APPENDIX A TIME ERROR CORRECTION PROCEDURES INITIATION TERMINATION TIME ERROR-SECONDS TIME ERROR-SECONDS TIME OF ALASKA ALASKA INITIATION INTERTIE INTERTIE --ON DAYS HAVING PEAK PERIOD -- ANY +2 +.1 NOTE:The Interconnection Monitor may postpone or cancel a time correction if requested to do so by regions or systems comprising 30 percent or more of the total frequency bias in the interconnected area,or if warranted by the overall capacity situation. REVISED APPROVED INSTRUCTIONS FOR USING THE ALASKA INTERTIE OPERATIONS HOURLY DATA AND SUMMARY SHEET This data and summary sheet will be the basis for monthly accounting.Entries should be made hourly by the intertie opera- tors and reconciled at 0600,1400 and 2200 daily. Twenty-four (24)hourly data columns and three "to *summary columns are provided in addition to the "daily total"column which should equal the sum of the columns from 0100 to 2400.The "forward total”column is the value of the "month to date”column brought forward from the previous day.The "month to date"column is the sum of the "daily total"and "forward total"columns. The top section is provided to record actual meter readings and to calculate the midpoint reading.For power flow to the north,the "meter”row equals one half of "Healy South In®*plus "Douglas North Out"plus "Cantwell In"row values.For power flow to the south,the "meter"row equals one half of "Healy South Out"plus "Douglas North In*minus "Cantwell In"row values.The value of the "meter”row is transferred to Row 1 with a plus sign if the flow is north or a minus sign if the flow is south.Row 2 is transferred up from Row 21.Inadvertent,Row 3,is Row 1 minus Row 2.Row 4 or Row 5,on or off peak,as appropriate,is the sum of Row 3 and the appropriate accumulated inadvertent from the pre- vious period.For the purpose of this sheet,the convention was chosen that POWER FLOW NORTH IS PLUS and POWER FLOW SOUTH IS MINUS.The signs of Rows 1 to 5 are significant.All values in Rows 7 through 20 are to be entered as positive values.Rows 7 to 12 and 14 to 19 are transferred from the appropriate "Alaska Intertie Transaction"sheets.Row 13 is the sum of power flowing south (listed as a positive value)and Row 20 is the sum of power flowing north (listed as a positive value).Row 21,"Scheduled Net Interchange”is Row 20 minus Row 13.The sign of Row 21 shows the correct direction of power flow on the intertie.Row 22 is the sum of Row 20 and Row 13 and is the value upon which APA O&M charges are based.APA O&M energy charges would be billed on the "month to date"values for the last day of the month as follows: to FMUS the sum of Rows 14,16 and 18;to GVEA the sum of Rows 15,17 and 19;to AML&P the sum of Rows 7 and 10;to CEA the sum of Rows 8 and 1l;to HEA the sum of Rows 9 and 12. Individual participant's transmission access charges would be based upon the total energy entering their system as summed from the individual "Alaska Intertie Tranaction"sheets. ALASKA INTERTIE OPERATIONS HOURLY DATA &SUMMARY SHEET DATE:oo ||||To ||||i |To i '||\|'to 'DAILY |FORWARD |PONTHe.ee |ews!eoee |wen)ee aan |asen |even)enon |eves!tame!sige ize:isan!ice]cap]sam ices «61768 \ege «1908 2009|2108 220m |22ep |2208 =24a |TOTAL TOTRL TO DATE METER §72(H,+00%C)or 1/2(HorD,-C)i bof:;ois -_-}---++-}--$bony -f---t---==-_-_4 -- HEALY SOUTH IN |to!aeeeeeeeeeeSe.pope a ae rs +--}--f----f----J --.-out -on on eo _L |i DOUGLAS NORTH IN |.:i |fT _ out ||7 a CANTWELL IN ' 2STPropespsstopsorpeeaadrbaLeapsekwerepewtectoege*t ro re Ty ye Tv nN oiling:aditedieal Gaaiieatiin Calitadin inti dani!+h -Si the Sait Eadie aieteindinOMEGini Catedt BEd ts sotfecepesp pe Ga a oa :MIDPOINT (+IS NORTH -IS SOUTH)f ; ; ->fa +cake Siena aie =re tee Bee - L.ACTUAL NET INTERCHANGE -_| CCALAULATED METER READING)[:i!2.SCHEGULED NET INTERCHANGE C219]|||||]|| a ee 3.INADVERTENT (1-2)= i |iodo yo a |--}--+--|.as oon Gee 4.ACCUMULATED INADV.ON PK Pop |i fot 1 py tf a ee -+--4 fue f--s-i.ate fp-pe-t-fe--}S.ACCUMULATED INADV.OFF PK lo:-7a nie oe earea.Top pe poe =pee Sec loctmae Sennen aaadinan ieee ashe aw fe - > f OPT ER TR Re wre Pe te ptt poe:SCHEDULES '_.eS ,:a i oY py ead -.-os Vaal trata:Sete Senin eed mae ee fae wpa few Po 4.eh 2 Re --]SOUTH ;tk 'an on Tos fps , 7.FNUS TO ANLP ||ee ee ee }----4 --_=&=-= 8.CEA | 3.HEA |.a 16.GVER TO ANLP |tot 11.CEA | 12.HEA - 13.SUBTOTAL SOUTH 748+9+18411412 , NORTH S >:."os iy q -_-;"\S =:'.:BS Dae := T - oo 14.ANLP TO FNUS ,- -_- -+--fF.-.-ov nee -+---f---mae ee -_- 15.GVEA 14 | 16.CEAR TO FRUS 17.GVEA 18.HEA TO FAUS ___ _f) 19.GVEA r ae =|_t.oe 28.SUBTOTAL NORTH 144....419|||"+or eee ae ----f ---fF -TO t---- F--|-7-FT --- 21.SCHEOULED NET INTERCHANGE (28-13)|-wee ee wp ee Fab ep ee fee es re a oes -or oo ee Cs os ee -f$--> 22.SCHEOULED TRANSFERS (26413 )i |I |[[| USE FOR SUNDA OR HOLIDAY ONLY ALASKA INTERTIE OPERATIONS HOURLY DATA &SUMMARY SHEET DATE:||]pod |To |||To DAILY |FoRHeRD |MONTH.oo esos |eves |aoe |ee ae ae was!ees |eas:ems |tree:12@0:13m0 |eae |cao |sas |ican |1700 |198 |se0 ce!2108 |22001 2200 2308 |2eeo |TOTRL TOTAL TO DATE METER (26H,Dor)of 1/2(Hord,-C)||[.!||t ae tt}een coe oe a oe ees ee _eo HEALY SOUTH IN uh [chie :i |: oo.Loge fiat abo b.hod es ee ee ee Ce Gn ouT Dt { 7 pny mate t 4 -=oe +in eee een eeee Oe +epee oe pe DOUGLAS WORTH IN __|oe ee ee -| out Pops i : _ee eee RE hp bb dpe. CANTWELL IN Poy Popo t :pay i,Sop pope aawahf- 4 re Gees Se 4th oaks if -es Oe ee Sa o4e-4es See ee es SaMIDPOINT(#IS NORTH -IS SOUTH)|;f k {[i Pw Be ce fee eee eh wate &of ie os Se ae os ron oneness -ao roy Po on =eee L.ACTUAL NET INTERCHANGE i bo | (CALAULATED METER READING)|i {'|, _bob pe pe.ao {.we _ 2.SCHEDULED NET INTERCHANGE (21)!pI ae oe a Lp re oe 3.INADVERTENT (1-2)|i | :too RO ow per toe ne Sa alien vhs oa Glee nina aed SS lied nent Dasa Mia and eet hanoed - 4.ACCUMULATED INADV.ON PK =q PeCone nein SOs SUS Oe GO es os te bb oe |osS.ACCUMULATED INADV.OFF PK 'a ee oc Sern -4 f Set ord ye ae --.Pa -ae oes SCHEDULES L L } -an)eanaet 0 - Fes ous Cinta Dine ie nn Ge bd 7 fo naa aan -ww Pet he et Resee 7SOUTH -a>fir pi}fon ee ae a boob pL DO Popp o4e ----a fee fe abowpio.bf 2...ob 7.FnuS TO ANLP |i ;|| ---f -4--a oS oe -_1 a 8.CEA L |r a fey -Le pepe ft pp bok __ 8.HEA _aq |{[et ||.7 ! 16.GVER TO AMLP ||i |mat -wofe pete bf eb f - |Pemto fee -- a.CEA _I L.-tf ee ee po! 12.HEA Feb be gE EL bE _ro |fo].i13.SUBTOTAL SOUTH 7+8+9+10¢11412 yy _' | ||a oe ony Saaa Eeiedh Gail inated wines Giihed:aainin fname Gnaied winetd bl 2 o °ore te ede ew eh wos ere oe ]TrWORTH --Pope pa tn a ape-f--f--R -fe bee +at --4+p--f--p f+.fee ef - 14.AMLP TO FRUS 4 _wh _f.Pot ota15.GVEA en _ae ;ti. 16.CEA TO FhUS tT atpa=-_-on areas _t 7T _-a i 17.GVEA boo |aa t +-"ee .a t aan -- 18.HEA TO FRUS |pee beeen _eee eee 19.GVEA :;t.7weePeeeeeei.;+.- 20.SUBTOTAL NORTH 14*....¢19 . Oo -ot niet .aoe --e &7 r ¢r e '21.SCHEDULED NET INTERCHANGE ::pS I . ¢28-13 >Pot PY .}4 -_-_---.woe eee e ee |cele eet ditties deat ot -.'s .22.SCHEDULED TRANSFERS (28413 );|| ALASKA INTERTIE SCHEDULING PROCEDURE A participant desiring to schedule a transfer on the intertie will contact the operator at their end providing the data at the top of the "Alaska Intertie Transaction”sheet and the schedule of hourly receipts.The operator will complete the transaction sheet,forward the data to the other operator and provide a copy to the participants in question.The midpoint schedule will betransferredtothedataandsummarysheet.The order of receipt of transaction requests will determine the appropriate losses. For example,if FMUS requests 1lOMW from AML&P,then GVEA requests 1OMW from CEA,the FMUS/AML&P transaction intertie hourly losses would be 0.05MW and the GVEA/CEA transaction intertie hourly losses would be 0.14MW.Prior to the start of each day,as pro- vided in the contract,both operators would concur on the schedule and inform all concerned participants.Provisions to transfer thetransactionsheetsandthescheduleportionsofthesummarysheet should be via Decnet or verbally until Decnet is available. ALASKA INTERTIE TRANSACTION SS DATE //TIME :TRANSACTION DATE // REQUESTED BY START TIME //s RAMP RATE /STOP TIME //' SUPPLIER RECEIVER CLASS OF ENERGY 0100 0200 0300 0400 0500 0600 0704 0800 0900 100 1100 2200 130Q 1400 1500 1600 1700 180G 1900 2000 2100 220q 2300 2400 TU.. CLL ZEHNDER (PMUS/GVEA) : :« (2)LLOSS t0NE Gl (3)|HEALY (4)L172 Loss tone 7) (3)|_MIOPOINT (6),1/2 Loss tone 7) (7)L_Douctas (8).LOSS ZONE ClCoestose we as pre ren pene -..f .:pi .°soe .. (10)]PLANT.2/230 ya (CEA/AMLP):: . (119 LOGS ZONE (C14+C2)-% (22)|sotooma.(CRA/BEA)_4 INSTROCTIONS FOR USEs Start by listing the desired echeduled power in whole MW's for the Receiver,Fill in each row sequentially toward the supplier(either up or down the sheet).The values for losses are obtained from the "ALASKA INTERTIE TRANSFER INCREMENTAL LOSS TABLE"or an on-line low fLlowProgram.The losses are to be scheduled in whole MW's (i.e.a loss of .11 Mi would be echeduled as 1 MW every 9 hours and O MW inbetween).The sche-Gule for each subsequent station ise the sus of the previous station plus any losses between etations.The schedule at the entrance station for se systenietheamountuponwhichwheelingchargeserebased.Line S is transferred to the Intertie Schedule and is the schedule upon which APA charges are based. LINE DEFIWITIONS:Line 1 =interchange between PMUS/GVEA at Zehnder;Line 2 -incremental losses between Zehnder and Healy on GVEA system;Line 3 -interchange between GVEA/AK Intertie at Healy;Line 4 =incremental loeses batween Healy and Midpoint equal to one half of AK Intertie losses;Line $-AK intertie schedule;Line 6 =incremental losses between Midpoint and Douglas equal to one half of AK Intertie losses;Line 7 -interchange between AKIntertie/CRA at Douglass;Line 8 -incremental losses between Douglas and University or AMLP on CEA systems Line 9 -incremental losses between DouglasandAKLPonNEAsystem(Applicable only when Pt.McKenzie =Teeland CEA lines are out of service);Line 10 -interchange between CEA/ANLP at Plant 2.Line 1l -incremental losses between Douglas and Soldotna on CEA system (not to be used with Lines @ &9);Line 12 =interchange between CEA/BEA atSoldotna. ALASKA INTERTIE -OPERATING COMMITTEE - DESIGNATED REPRESENTATIVES AND ALTERNATES PARTICIPANT REPRESENTATIVE ALTERNATE PHONE NUMBER *eGLVLELA.Bob Orr 452-1151 G.V.E.A.Marvin Riddle **C LEA,John Marshall 564-0603 C.E.A.Ray Duncan 564-0789 **ML&P Mike Massin 263-5222 ML&P John Cooley 263-5450 **FMUS Larry Colp 456-5168 FMUS Alan Martin 452-7109 *A.P.A.(State)Afzal H.Khan 276-0001 A.P.A.(State)Howard Thacke **AEG&T Sam Mathews 235-8167 AEG&T Ken Ritchey 745-3231 *Participant **Utility Participant Effective November 1985 9894/482/7 ALASKA INTERTIE -OPERATING COMMITTEE - SUBCOMMITTEES I.Relay/Protection Subcommittee II.Handbook/Procedures Subcommittee III.Machines/Rating Subcommittee IV.Reserves/Load Shed Subcommittee VY.$S.V.S.Evaluation Subcommittee **vacant chairmanship VI.S.C.A.D.A./Metering/Communications Subcommittee VII.Dispatch/Scheduling Subcommittee VIII.Budget Subcommittee 9894/482/8 *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 Howard Thacke Hank Nikkels Larry Hembree Alan Martin Afzal Khan John Marshall Harry Beck 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 *Mike Massin CEA MEA ML&P APA GVEA AEG&T ML&P GVEA CEA ML&P GVEA FMUS GVEA CEA APA ML&P ML&P FMUS APA CEA APA 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 ML&P Bob 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 PROJECT CONTRACT AGREEMENT OPERATING COMMITTEE DUTIES AND RESPONSIBILITIES PER 8 !S-8S5 DRAFT THE AUGUST 15,1985 DRAFT OF THE ALASKA INTERTIE(ANCHORAGE/FAIRBANKS )AGREEMENT ESTABLISHES AN "OPERATING COMMITTEE"UNDER ARTICLE 9 OF THE MAIN BODY OF THE AGREEMENT AND VARIOUS SECTIONS OF THE MAIN AGREEMENT ,THE ADDENDUM#1 (RESERVES ) AND EXHIBIT A REFER TO THE DUTIES 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,SCHEDULED/ACTUAL POWER AND ENERGY DELIVERIES. PAGE &,3.1.11,LOG SHEETS AND OTHER RECORDS. PAGE 6,3.1.11,DATA FROM METER REGISTRATIONS AND OTHER SOURCES. PAGE G,3.1.12,ADDITIONS/MODIFICATIONS TO ESTABLISHED SCHEDULES.eePAGE 7,3.2.3,COORDINATED LOAD SHEDDING. PAGE 7,3.2.4,COORDINATED RELAYING AND CONTROL DEVICES. PAGE 7,3.2.5,REGULATION OF REAL AND 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(DESIGN AND CONST). PAGE 13,7.4.2,COSTS RELATED TO MODIFICATIONS AND ADDITIONS. PAGE 13,7.4.3,DETERMINATION OF DIRECT BENEFITS. PAGES 17 THROUGH 21,ESTABLISHMENT OF THE "OPERATING COMMITTEE”. PAGE 23,10.2.1,OPERATION OF THE INTERTIE ,SUSPENSION OF WORK. PAGE 24,10.3.1,BUDGET FOR OPERATION OF THE INTERTIE. PAGE 26,11.t.1 AND 11.1.2,AML&P AND GVEA SCHEDULING RESPONSIBILITY. PAGE 27,11.2.5,MODIFICATION OF POWER AND ENERGY SCHEDULES. 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 AND APPROVAL OF PARTICIPANT INSURANCE REQUIREMENTS. PAGE 35,17.3.2,PROOF OF INSURANCE. PAGE 39,25.1.2,NOTICES AND REQUESTS OF A ROUTINE CHARACTER. PAGE 2,ADDENDUM #1,A-1.1.2,RESERVE CAPACITY OBLIGATION. PAGE 2,ADDENDUM #1,A-1.1.3,ANNUAL ACCREDITED CAPABILITY DETERMINATION. PAGE 2,ADDENDUM #1,B-2.1.1,SPINNING AND NON-SPINNING RESERVE. PAGE 2,ADDENOUM #1,B-2.1.2,MODIFICATIONS TO OPERATING RESERVES ,ETC. PAGE 3,ADDENDUM #1,B-2.2.3,MODIFICATIONS OR CHANGES TO GENERATING UNIT CAPABILITY FOR OPERATING RESERVES. PAGE 3,ADDENDUM #1,B-2.3.1,ALLOCATION OF OPERATING RESERVES. PAGE 4,ADDENDUM #1,B-2.4.2,SPINNING RESERVE THROUGH AUTO LOAD SHEDDING. PAGE 4,ADDENDUM #1,B-2.4.3,ASSURANCE OF SYSTEM OPERATING RESERVE. PAGE 5,EXHIBIT A,DEFINITION #29,OPERATING COMMITTEE. PAGES 1 AND 2,EXHI8SIT D,MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS DET- MINATION. UTILITY PARTICIPANTS'REPRESENTATIVES AND THEIR ALTERNATES WHO SIT ON THE OPERATING COMMITTEE ARE ENCOURAGED TO THOROUGHLY REVIEW THE LATEST DRAFT AGREEMENT AND BECOME FAMILIAR WITH THE PROVISIONS OF THE AGREEMENT WITH EMPHASIS ON THE DUTIES ANDO RESPONSIBILITIES OF THE OPERATING COMMITTEE. .. : .;ett "be at.re?fagjo[4 <o t Intertie Task Force October 14,1985 Harry L.Beck Intertie Operating Committee Operations Engineer October Meeting Summary At the October Intertie Operating Committee meeting held on October 9,1985,the following was discussed: Transmission Line: 1.Line work associated with Pt.Mackenzie-Teeland circuit upgrade will be completed within the week. 2»Anchorage Municipal Light &Power (MLP)has been keeping the southern side of the Intertie energized with the switch open at Cantwell.The Intertie is being used as a +14 MVAR shunt capacitor (i-e.distributed capacitance of the open line) and is therefore helping to hold voltage at the Teeland 138 kV bus. 3.APA's letter af nonabjection to Intertie use for testing was. sent to General Managers of concerned utilities during latter part of week of September 29,1985.Most of the members of the Intertie Operating Committee had not seen this letter and therefore couldn't comment on or concur with it.Jim Hall representing Matanuska Electric Association (MEA)commented that MEA was uncomfortable with the arrangement as any major disturbance arising out of the testing could cause the MEA system to experience a total loss of power. 4.Present MEA load is about 55 MU.Power for MEA is being dispatched from MLP.plant #2 and Eklutna through the "backdoor"(i.e.Eklutna-Dow Tap circuit energized). Consensus at meeting was that this line should be load tested to determine what the real capacity of this line. This has never been determined.MEA is concerned that the thermal limit of this line will be exceeded by the GVEA-MLP Intertie load testing in 3.above.Mike Massin,Chief Engineer MLP,suggested that thermal limit of this line may not be reached due to excessive valtage drop down the line due to small size of this conductor (397 ACSR). Transformers: 1.The new Chugach Electric Association (CEA)250 MVA,230 kV - 115 kV transformer at Teeland is due to be installed at the end of November.This transformer will replace the existing 46 MVA,138 kV -115 kV transformer which serves the MEA system.Testing and checkout is expected to take until the first af the year. 2.The APA 100 MVA transformer at Goldhill substation is now the only one there in service presently carrying about 20 MW. SVS3 1.We are still experiencing failure of thyristor assemblies (cells)during actuation of emergency shutdown.Normal shutdown adjusts output susceptance to O (Y¥Y,=Yce)before deenergizing SVS bus.This adjustement is bypassed during emergency shutdown. 2.The technicians working on the Static VAR systems have left the sites and are not.expected to return until January 1986. At that time they will finish the SVS startup modifications required at the Teeland substation.COR werk ©-Tee/n2/°(tesle 26,a 7 7°F (CPeees AP,most Se Com y Ptr De of Bir st. SCADA: 1.ML&P and Golden Valley Electric Association (GVEA)will be completing their SCADA system testing within the next two days.»Their tests will be conducted at the maximum data transmission rate of 9600 Baud. 2.GVEA is installing bubble memory metering equipment at their substations in order to have a means of comparison with the remote metering indication furnished as a part of the SCADA system.The SCADA metering equipment is used for recording energy purchases and sales (revenue metering).GVEA feels it's important to have another means to check the accuracy of this revenue metering equipment.SCADA metering equipment is now installed at the (1)Cantwell],(2)Teeland, (3)Healy,(4)Goldhill,(5)Douglas and,(6)Zehnder substations Morris-Knudsen Presentation: 1.Lee Warnock,Morris Knudsen,stated that there is a test procedure for the SVS called a "loss"test.Bob Orr,GVEA, said that he didn't know what a joss test was.He further stated that he wanted to see an acceptance test for the SVS for review. 4. 5. Mike Massin recommended that MK forward copies of this loss test to all of the concerned parties for review now.Bob Orr recommended that MK,APA and Gilbert/Commonvealth (G/C) review this loss test to ensure that it meets the requirements for the SVS as identified in the specifications. Operating Committee was concerned that no acceptance test or procedure of any kind has ever been received by the utilities for review.Lee Warnock,Morris Knudsen,stated that a test procedure exists for each substation and line segment.Bob Orr stated that he wanted to see an acceptance test and punchlists for these substations. Marvin Riddle,GVEA,stated that a lot of work still remained to be completed at Healy substation and that GVEA had requested punchlists for Healy &Goldhill substations long time ago"but had never received them. a Lee Uarnocky stated that MK owes APA a final test report. MK has still not been able to get Westinghouse technicians to install temperature probes on the SF.breakers at all of the substations.These breakers experience low gas pressure trips (nuisance)at low temperatures.CEA even experiences this problem with their SF.breakers at Daves Creek substation which serves the city of Seward.The consensus of the Committee is that this problem is a design defect that must be corrected by Westinghouse before these breakers will be accepted by the utilities. Lee Warnock'stated that he had come to the meeting to say"thanks for'the memories."The consensus of the Committee members was that MK's "swan song"was much to premature, that significant items still remained to be resolved aon this project. Dynamic Stability Study: 1.The computer model/database for the Anchorage-Fairbanks interconnected power system has been completed.The only data that has not been reviewed and entered is the relaying data for the CEA system.This item will be completed by the end of this week.The computer runs for the stability study are scheduled to start the latter part of next week at the University of Alaska-Fairbanks (UAF).Harry Beck will be present in Fairbanks during the computer analysis to provide technical support and oversight.The completed model/database and the final report will be presented to the Intertie Operating Committee at the November meeting. 2.The database along with the EPRI software and documentatian necessary to use it will be turned over to the Intertie Operating Committee to use and maintain.The APA account at the University of Alaska Computer Network (CUACN)where the database is stored is "FRAPA."John Aspnes,UAF,will be available for praviding help in using the database for the Northern area utilities.Harry Beck,APA,will be available for providing help in using the database for the Southern area utilities. It was suggested that the APA should maintain the database and the documentation for it.Harry Beck,APA,recommended that since the Operating Committee will control the use of the database,that they therefore should also maintain it and budget for it out it of the Committee's O&M budget.He further stated that the APA doesn't have the staff necessary to maintain this project and that we would likely contract it out to UAF (as they're better equipped to do this)anyway as an O&M expense. John Aspnes will present a proposal at the November Intertie Operating Committee regarding new system studies for theoperationoftheinterconnectedAncharage -Fairbanks power network. Miscellaneous: 1.The Committee expressed the opinion that the workload of the Committee would probably not decrease for the first year of commercial operatior of the Intertie.-The Committee wil] therefore still meet a minimum of once a month during this period. Homer Electric Association (HEA)&MEA will no longer be recognized as members of the Committee.Their representatives will now be treated as members of the Alaska Electric Generation &Transmission Cooperative (AEG&T),the recognized participant as identified in the Alaska Intertie Agreement. G/C has informed the Committee that Dan Rice has no longer any association with G/C and should therefore not be consulted in any way as a part of G/C obligations to the Committee or to the Intertie project. The Intertie Dispatch Schedule for Energy/Power Exchange as developed by the Dispatch/Scheduling Subcommittee was approved for an indeterminate (testing)period of time.It will be used for scheduling power exchange through the Intertie. The next scheduled meeting of the Intertie Operating Committee will]be at Fairbanks Municipal Utilities (FMUS)on November 13,1985. ccs Afzal Khan,Alaska Power Authority Rudy Etheridge,Alaska Power Authority Dave Eberle,Alaska Power Authority Ed Morris,Alaska Power Authority Howard Thacke,Alaska Power Authority Gloria Manni,Alaska Power Authority Eve Reeves,Alaska Power Authority Polep,3 |MEMORANDUM State of Alaska TO: FROM: Intertie Task Force pate:October 15,1985 FILE NO: TELEPHONE NO: Hes ;,Harry L.Beck suevect:Intertie Operating Operations Engineer Committee October Meeting Summary At the October Intertie Operating Committee meeting held on October 9, 1985,the following was discussed: Transmission Line: 1.Line work associated with Pt.MacKenzie-Teeland circuit upgrade will be completed within the week. 2.Anchorage Municipal Light and Power (MLP)has been keeping the southern side of the Intertie energized with the switch open at Cantwell.The Intertie is being used as a +14 MVAR shunt capacitor(i.e.,distributed capacitance of the open line)and is,therefore, helping to hold voltage at the Teeland 138 KV bus. 3.APA's letter of nonobjection to Intertie use for testing was sent to General Managers of concerned utilities during latter part of week of September 29,1985.Most of the members of the Intertie Operating Committee had not seen this letter and therefore could not comment on or concur with it.Jim Hall representing MatanuskaElectricAssociation(MEA)commented that MEA was uncomfortable with the arrangement as any major disturbance arising out of the testing could cause the MEA system to experience a total loss of power. 4,Present MEA load is about 55 MW.Power for MEA is being dispatchedfromMLPplant#2 and Eklutna through the "backdoor"(i.e.,Eklutna-Dow Tap circuit energized).Consensus at meeting was that this line should be load tested to determine what the real capacity of this line.This have never been determined.MEA is concerned that the thermal limit of this line will be exceeded by the GVEA-MLP Intertie load testing in 3.above.Mike Massin,Chief Engineer,MLP,suggested that thermal limit of this line may not be reached due to excessive voltage drop down the line due to smallsizeofthisconductor(397 ACSR). Transformers: 1.The new Chugach Electric Association (CEA)250 MVA,230 KV -115 KV transformer at Teeland is due to be installed at the end of Novem- ber.This transformer will replace the existing 46 MVA,138 KV -115 KV transformer which serves the MEA system.Testing and checkout is expected to take until the first of the year. 1563/478/1 Intertie Opera.j Committee October Meeting Summary October 15,1985 Page 2 2.The APA 100 MVA transformer at Goldhill substation is now the only one there in service presently carrying about 20 MW. SVS: 1.We are still experiencing failure of thyristor assemblies (cells) during actuation of emergency shutdown.Normal shutdown adjustsoutputsusceptanceto0(Y =Yo)before deenergizing SVC bus.Thisadjustmentisbypasseddurtngemergencyshutdown. 2.The technicians working on the Static VAR systems have left the sites and are not expected to return until January 1986.At that time they will finish the SVS startup modifications required at the Teeland substation. SCADA: 1.ML&P and Golden Valley Electric Association (GVEA)will be complet- ing their SCADA system testing within the next two days.Their tests will be conducted at the maximum data transmission rate of 9600 Baud. 2.GVEA is installing bubble memory metering equipment at their substations in order to have a means of comparison with the remote metering indication furnished as a part of the SCADA system.The SCADA metering equipment is used for recording energy purchases andsales(revenue metering).GVEA feels it is important to have another means to check the accuracy of this revenue meteringequipment.SCADA metering equipment is now installed at the (1)Cantwell,(2)Teeland,(3)Healy,(4)Goldhill,(5)Douglas and,(6)Zehnder substations. Morrison-Knudsen Presentation: 1.Lee Warnock,Morris Knudsen,stated that there is a test procedure for the SVS called a "loss"test.Bob Orr,GVEA,said that he did not know what a loss test was.He further stated that he wanted to see an acceptance test for the SVS for review. Mike Massin recommended that MK forward copies of this loss test to all of the concerned parties for review now.Bob Orr recommended that MK,APA and Gilbert/Commonwealth (G/C)review this loss test to ensure that it meets the requirements for the SVS as identified in the specifications. Operating Committee was concerned that no acceptance test or procedure of any kind has ever been received by the utilities for review.Lee Warnock,Morris Knudsen,stated that a test procedure exits for each substation and line segment.Bob Orr stated that he wanted to see an acceptance test and punchlists for these substa- tions.Marvin Riddle,GVEA,stated that a lot of work still 1563/478/2 Intertie Operating Committee October Meeting Summary October 15,1985 Page 3 remained to be completed at Healy substation and that GVEA had requested punchlists for Healy and Goldhill substations "a long time ago"but had never received them. Lee Warnock stated that MK owes APA a final test report. MK has still not been able to get Westinghouse technicians to install temperature probes on the SF,breakers at all of thesubstations.These breakers experiefce low gas pressure trips(nuisance)at low temperatures.CEA even experiences this problem with their SF.breakers at Daves Creek substation which serves thecityofSeward.The consensus of the Committee is that this problem is a design defect that must be corrected by Westinghouse before these breakers will be accepted by the utilities. Lee Warnock stated that he had come to the meeting to say "thanks for the memories."The consensus of the Committee members was that MK's "Swan song"was much to premature,that significant items still remained to be resolved on this project.. Dynamic Stability Study: 1.The computer model/database for the Anchorage-Fairbanks intercon- nected power system has been completed.The only data that has not been reviewed and entered is the relaying data for the CEA system. This item will be completed by the end of this week.The computer runs for the stability study are scheduled to start the latter partofnextweekattheUniversityofAlaska-Fairbanks (UAF).Harry Beck will be present in Fairbanks during the computer analysis to provide technical support and oversight.The completed model/data- base and the final report will be presented to the Intertie Operat- ing Committee at the November meeting. The database along with the EPRI software and documentation neces- sary to use it will be turned over to the Intertie Operating Committee to use and maintain.The APA account at the UniversityofAlaskaComputerNetwork(UACN)where the database is stored is "FRAPA."John Aspnes,UAF,will be available for providing help in using the database for the Northern area utilities.Harry Beck, APA,will be available for providing help in using the database for the Southern area utilities. It was suggested that APA should maintain the database and the documentation for it.Harry Beck,APA,recommended that since the Operating Committee will control the use of the database,that they therefore,should also maintain it and budget for it out of the Committee's O&M budget.He further stated that the APA does not have the staff necessary to maintain this project and that we wouldlikecontractitouttoUAF(as they are better equipped to dothis)anyway as an O&M expense. 1563/478/3 Intertie Opera..ig Committee October Meeting Summary October 15,1985 Page 4 4,John Aspnes will present a proposal at the November Intertie Operating Committee regarding new system studies for the operation of the interconnected Anchorage-Fairbanks power network. Miscellaneous: 1. 5. The Committee expressed the opinion that the workload of the Committee would probably not decrease for the first year of commer- cial operation of the Intertie.The Committee will,therefore, still meet a minimum of once a month during this period. Homer Electric Association (HEA)and MEA will no longer be recog- nized as members of the Committee.Their representatives will now be treated as members of the Alaska Electric Generation and Trans- mission Cooperative (AEG&T),the recognized participant as iden- tified in the Alaska Intertie Agreement. G/C has informed the Committee that Dan Rice has no longer any association with G/C and should therefore not be consulted in any way as part of G/C obligations to the Committee or to the Intertie project. The Intertie Dispatch Schedule for Energy/Power Exchange as devel- oped by the Dispatch/Scheduling Subcommittee was approved for anindeterminate(testing)period of time.It will be used for scheduling power exchange through the Intertie. The next scheduled meeting of the Intertie Operating Committee willbeatFairbanksMunicipalUtilities(FMUS)on November 13,1985. HB/tg cc:Afzal Khan,Alaska Power Authority Rudy Etheridge,Alaska Power Authority Dave Eberle,Alaska Power Authority"Ed Morris;Alaska Power Authority Howard Thacke,Alaska Power Authority Gloria Manni,Alaska Power Authority Eve Reeves,Alaska Power Authority 1563/478/4 UNIVERSITY OF ALASKA-FAIRBANKS Fairbanks,Alaska 99701 Date:October 8,1985 To:Alaska Intertie Operating Committee PL)From:John aspnestond George Mulligan' We enclose a preliminary proposal for your consideration. Our interest is in providing database management and system analyses relevant to intertie operation.We believe that the proposed project will provide useful services to railbelt utilities as well as enhance educational opportunities to UAF students specializing in electric power.The project is a logical extension of the intertie dynamic stability study which is nearing completion. We would like to obtain feedback from the committee,refine these preliminary ideas and present a formal proposal at the November 1985 meeting. JA:DP:1824 SE86.16 PRELIMINARY PROPOSAL TO ALASKA INTERTIE OPERATING COMMITTEE SYSTEM ANALYSES AND DATABASE MANAGEMENT by John Aspnes George Mulligan Institute of Water Resources/Engineering Experiment Station University of Alaska-Fairbanks Fairbanks,AK 99775-1760 October 1985 PROJECT SCOPE Project tasks to be performed include: 1.provide data management for railbelt utilities associated with the Alaska Intertie;and perform system analyses on the interconnected Anchorage and Fairbanks electric power networks. Analyses may include: a)powerflow b)transient stability c)mid-term stability d)impact of spinning reserve utilization on mid-term stability e)short-term and long range economic studies f)system reliability g)load shape forecasting h)effects of reduced voltage on system operation and efficiency. Acquisition and implementation of new computer programs to reside on UAF computer and be available for system studies. Computer hardware improvement necessary to provide project support. Re Te Timetable January 1986-August 1987 January 1986-June 1986 July 1986-June 1987 July 1987-August 1987 PROJECT SCHEDULE Tasks Manage database developed by dynamic study project. Review computer programs and acquire those most useful for future system studies. Specify and purchase computer hardware. Perform system analyses determined in consultation with Intertie Operating Committee.Write final reports for individual system studies as completed. All reports and final summary report to be completed by August 31,1987. BUDGET SALARIES 1.Principal Investigator,J.Aspnes 10 weeks Coinvestigator,G.Mulligan 10 weeks Two Graduate Students, $13,000/yr Secretary 1 week>wine).Py°LEAVE BENEFITS 1.16.1%of A.1,A.2 2.18.3%of A.4 STAFF BENEFITS 1.24.6%of A.1,A.2 and B.1 2.26.6%of A.4 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 2.10M byte disk drive for School of Engineering VAX computer 3.Two PC-XT computers and peripherals OVERHEAD 1.39.2%of Modified Total Direct Cost (items A through F) TOTAL COST OF PROJECT $14,423 11,538 26,000 554 4,180 101 7,415 174 3,000 800 500 700 700 200 20,000 3,500 7,000 27,952 $128,337 UNIVERSITYOF ALASKA FAIRBANKS Fairbanks,Alaska 99701 October 8,1985 Mr.Harry Beck Alaska Power Authority 334 W.5th Avenue,2nd Floor Anchorage,Alaska 99501 Dear Harry: The project titled "Dynamic Stability Study of the Anchorage- Fairbanks Interconnected Power System"is approaching completion. I hope that the latest database revision will be completed in about 1 week and that the final report will be available by early November. Since the beginning of this project,it was planned by all participants that the database and an executable image of theElectricPowerResearchInstitute(EPRI)745 powerflow,stability and plot programs reside on the University of Alaska ComputerNetwork(UACN)VAX 11/785 computer located in Fairbanks. To provide access to the database and EPRI 745 programs, individual accounts for each of the four participating utilitiesandtheAlaskaPowerAuthority(APA)have been set up with UACN. These accounts will allow individual database copies to be available for each utility to use and modify without altering a master copy which would be altered only through more formalprocedures.The account for Alaska Power Authority (APA)isidentifiedbytheusernameFRAPA.(Initial Password =2760001.) UACN is not accepting commercial accounts.Therefore I have assumed responsibility for the accounts set up for the utilities and APA.UACN will bill the School of Engineering for FRAPA costs incurred from your use of the account.I will,in turn, bill APA for those costs. The current charge rates by UACN are enclosed.I don't know how much use your account will experience over the next 12 months,but assuming three two-second stability cases run in _batchprocessingpermonth,the cost in CPU time would be about$2200/year.A two-second stability simulation requires about 47 minutes of CPU time.Powerflow takes about 2 minutes CPU time for the entire Anchorage-Fairbanks system.Allocated disk stor- age for 5000 blocks will add about $80/year.Assuming terminal UNIVERSITYOF ALASKA-FAIRBANKS connect times of 10 hours/month adds about $312/year.Consider- ing printing,I/0 charges and anything else I may have over- looked,$4000/year may be a reasonable amount to budget for this purpose.You may want to increase this amount if greater use is anticipated. The software center providing EPRI computer programs and documentation has agreed to sell enough copies of the complete 745 program documentation to me so that I can in turn provide a copy to each utility for between $75 and $100. A preliminary proposal to the Intertie Operating Committee titled "System Analyses and Database Management is being submitted today.If acceptable to all parties,I would prefer to build UACN costs into that proposal.This would,I think,benefit everyone.The utilities and Alaska Power Authority could use the existing committee as a vehicle to reimburse the School of Engineering for UACN charges while the School of Engineering would only have to recover the charges from one source rather than five. I need a short note from APA indicating willingness to pay for its use of UACN services and program documentation.Also,it is necessary that I will always have at least read permissions in the FRAPA account files,since I have responsibility for that account. I will be sending you further information about the VAX 11/785, program information and the database as it becomes available. Please let me know if you have any questions. Sincerely, John Aspnes,P.E. Head Electrical Engineering Department 539 Duckering Building University of Alaska-Fairbanks Fairbanks,Alaska 99775 (907)474-7137 JA:DP:1823 ALASKA POWER AUTHORITY 334 West 5th Avenue, 2nd Floor Anchorage,Alaska 99501 . (907 278-0001 _Telephone Conversation Record(907)277-7641 Date _/°/7 /8S_time __8429 Stam Clem Project No.73.2 Jt.Cj From 3)Faw L gm WMaclu7i Recorded By Deve fated Company MEA Phone No._775.-32 3/ ,7FIS-928)(MacLwro:») Address Project Name Arech -Frxs Jor PEt SUBJECT:Sree Wet y nroarimn ar Sorvennz 359 L carte Din far ro ASK JE SVEA vwiivip KE pyOrntirte free AINA 70)Pom SomE Roem wonk ow FH Inrnre, Jv VEMW of TH Frer gear MEA Wal ving Be ppnowes ZHE Ly-Ma FA elcayoo pe Serjeves vr wisi 2s e 4VALVSLEExpectfon14peurFeypeat are overt Bpeklob6OD os zHEere own wonke./+e prkin Foor DT 714 70 om Mac |rerosH SHH DLRAANSG 8 Rm GOVE. Me_Mac/wrosh _fts0 _péetto Thr JT -wIivr10 BE Coop Exrtrilvcs Fon MEA ,Ku PALS EWILY THEY Lee NO MATOtteOE Poet ftir Mun zootls pew LOUOembnr FO vn pa THO Ite,He tvrevig> Howiver. tset "zo Sone flontG oret oF HIS MEOrLE Fe 9B SERVE ove; -RtrYare orttianre Fm purnt eKersuce+I forwety ro marek BA SPACE SVUAIC POLE ro I |ante wove Ca27e 7°evs le x ee an PATE TO:Afzal Khan DATE:September 5,1985 Director/Systems Operations &Engineering FROM:Harry L.Beck SUBJECT:Intertie Operating Operations Engineer Committee Meeting The Intertie Operating Committee meeting scheduled for September 11,1985 has been postponed to October 9,1985. The subcommittee meetings scheduled for September 10,1985 have been postponed to October 8,1985.These postponements were necessary due to travel to Juneau on September 11th by Mike Massin (AMLP)&John Marshall (CEA)and due to the energization and testing of the Gold Hill transformer by Golden Valley personnel scheduled for the week of September 9th. cc:Ed Morris,Alaska Power Authority Howard Thacke,Alaska Power Authority ALASKA POWER AUTHORITY "4 WEST 5th AVENUE -ANCHORAGE,ALASKA 99501 Phone:(907)276-0001 August 15,1985 Mr.Michael P.Kelly General Manager Golden Valley Electric Association,Inc. P,0.Box 1249 Fairbanks,Alaska 99707 Subject:Modification of Liability Insurance Provisions for Alaska Intertie and Testing Agreements Dear Mr.Kelly: The requirement for $20,000,000 of liability insurancehas been reported to beaproblemforutilitiestoobtainandinpremiumcost.State risk management has been contacted to see if the provisions are appropriate,and if not,be reduced.Mr.Don Hitchcock,Director of Division of Risk Management reviewed the request and on August 9,1985 reduced the liability requirements to aminimumof$10,000,000. This change has now been incorporated in the attached Alaska Intertie and Testing Agreements.For your convenience,two complete copies of each are included for your use in your approval process.They are not signature copiesassixoriginalsforsignaturepurposesarerequired.Either a single signing meeting will be held or I will route the required copies to you for the required signatures. To determine the best way to complete the signature process I would like toknowyourschedule,for obtaining approval to enter into each agreement.Preliminary information indicates that most utilities will schedule for policy board review and action in September.This schedule may obviate the need for the testing agreement,but I suggest that it still should be considered for adoption to eliminate the possibility of the Alaska Power Authority not being able to declare "Commercial Operation"until later in the year. Please advise me of your schedule for consideration and adoption.If you or your staff have additional questions,call me at 276-0001,extension 214, _Attachment as stated.|Cn Sincerely, vee L.Morris Associate Executive Director of Planning ELM:it 696/440 August 15,1985 Page 2 cc:Afzal Khan,Alaska Power Authority,AnchorageAlaskaIntertieOperatingCommittee,(w/one letter,distribution list and one copy of each agreement) Mike Massin,Anchorage Municipal Light &Power,Anchorage Sam Mathews,Alaska Electric Generation and Transmission Co-op and Homer Electric Association,Homer Ken Ritchey,Alaska Electric Generation and Transmission Co-op and Matanuska Electric Association,Palmer John Marshall,Chugach Electric Association,Anchorage Larry Colp,Fairbanks Municipal Utility System,Fairbanks Robert Orr,Golden Valley Electric Association,Fairbanks Everett Diener,City of Seward,Seward Bob Cross,Alaska Power Administration,Juneau Dan Rice,Gilbert/Commonwealth,Bellevue,Washington,(w/one letter, distribution list and one copy of each agreement) 696/440 DISTRIBUTION LIST 8/15/85 Mr.Michael P.Kelly General Manager Golden Valley Electric Association,Inc. P.QO.Box 1249 Fairbanks,Alaska 99707 Mr.Robert Martin,Jr. General Manager Chugach Electric Association,Inc. P.QO.Box 3518 Anchorage,Alaska 99501 Mr.James F.Palin General Manager Matanuska Electric Association,Inc.P.QO.Box 1148 Palmer,Alaska 99645 Mr.Virgil Gillespie General Manager Fairbanks Municipal Utilities System P.QO.Box 2215 Fairbanks,Alaska 99707 Mr.Thomas Stahr General ManagerAnchorageMunicipal Light &Power.1200 East First.Avenue Anchorage,Alaska 99501 Mr.Kent Wick General Manager Homer Electric Association,Inc. P.0.Box 429 Homer,Alaska 99603 Record CopyFile#ft.Plo 3-4 ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,August 14,1985(At Municipal Light and Power,Anchorage) Attendance: Ken Ritchey Matanuska Electric Association John C.Marshall Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Mike Massin Anchorage Municipal Light and Power Ed Morris Alaska Power Authority Afzal Khan Alaska Power Authority Howard Thacke Alaska Power Authority Harry Beck Alaska Power Authority The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Municipal Light and Power main conference room. Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unani- mous ly, Bob Orr then motioned for the agenda to be adopted with modifica- tion -exclude item VI-F.Mike Massin seconded the motion and it was adopted unanimously. Under Committee's Correspondence and Reports,the Committee received no correspondence since the last meeting. Bob Orr gave a report on the meeting held by SCADA/METER- ING/COMMUNICATIONS Subcommittee.The meeting was held on Au- gust 13,1985 at 9:00 a.m.at the Chugach Electric AssociationEngineeringRoom.(Bob Orr also furnished the Operating Committeewithasetofminuteswhichareattached). Marvin Riddte also provided the Operating Committee a brief report on the Dispatch Scheduling Subcommittee meeting.This meeting was held on August 13,1985 at the Chugach Electric Association Engi- neering Room. Marvin Riddle indicated that John Cooley is working on Subcommittee Meeting minutes and forms.Marvin also indicated that he will complete and formalized transaction sheet and will be available at the next Operating Committee Meeting.A monthly format for billing will be ready by the next Operating Committee Meeting.Marvinnotedthatthefollowingshouldbediscussed:1)payback nexthour,2)inadvertent in opposite direction,3)automatic accounting system on EMS. Dispatch/Scheduling Subcommittee elected Marvin Riddle as the chairman.It is brought to committee's attention that the Teeland Substation modification is in progress.Marvin asked the Operating 9894/410 AIOC Minutes August 14,19€ Page 2 Committee to adopt NERC operating guide and the time error correc- tion with minor changes.Marvin indicated that he will have this ready for the next meeting. Reserves/Loadshed Subcommittee elected Marvin Riddle as the chair- man.Marvin Riddle provided the Operating Committee with a set ofminutesfromtheReserves/Loadshed Subcommittee Meeting.This meeting was held on Tuesday,August 13,1985 at 9:00 a.m.at the Chugach Electric Association Engineering Room. The Operating Committee thanks John Marshall for coming up with a good underfrequency load retention plan. Ed Morris from the Alaska Power Authority discussed the Alaska Intertie Agreement.Ed Morris indicated that AG is redrafting insurance section.The Operating Committee members requested Ed Morris to mail the complete Agreement instead of only revised pages. Afzal Khan then discussed field installation and testing of the repaired Goldhil]Transformer.The Alaska Power Authority is expecting a letter from General Electric regarding solution to the problems associated with Healy and Goldhill SVS system.The Alaska Power Authority will provide a microwave link between Eklutna Dam and Alcantra site.Afzal Khan acknowledged the receipt of Alaska Intertie Operating Committee Fiscal Year 1987 Budget from Chairman Mike Massin. There were no visitors present at the meeting. The Operating Committee had no old business to conduct at the meeting. The Operating Committee recessed into a break from 10:35 a.m.to 10:50 a.m. Turning to SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE,Bob Orr indicated that the minutes of Subcommittee meeting stands on its own.Bob Orr noted that DIVCOM is basically finished with the contract.He suggested that Alaska Power Authority should go through testing plan with the DIVCOM.Bob Orr requested an addi- tional channel between Fairbanks and Anchorage.Afzal Khan said he will check with Mike Ridge of DIVCOM. Turning to Dispatch/Scheduling subcommittee,Marvin Riddle indicat- ed that he has no other comments. Bob Orr noted that Underfrequency Loan Retention Plan is a self based document.No action is required by the Operating Committee. The Operating Committee should review and accept the Underfrequency Load Retention Plan. 9894/410 AIOC Minutes August 14,198 Page 3 Mike Massin brought to committee's attention that Gilbert/Commonwealth finished the work on Data Book and Operating Procedure Manual.Bob Orr suggested that these should be updated annually. Under Formal Operating Committee actions/recommendations,the Operating Committee has reviewed the Underfrequency Load Retention Plan and sees no problem with its contents.The Operating Commit- tee concurs with it.Again,the Operating Committee thanks John Marshall for the work done on Underfrequency Load Retention Plan. Turning to subcommittee assignments,Chairman Mike Massin then directed the SCADA/METERING/COMMUNICATIONS SUBCOMMITTEES TO MEET ON TUESDAY,SEPTEMBER 10,1985 AT 9:00 A.M.IN THE ENGINEERING CONFER- ENCE ROOM OF CHUGACH ELECTRIC ASSOCIATION for the purpose of status update on data link,complete metering and continue with revenue metering with emphasis on what should be done and how to do it. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM- MITTEE TO MEET ON TUESDAY,SEPTEMBER 10,1985 AT 1:00 P.M.AT THE CHUGACH ELECTRIC ASSOCIATION ENGINEERING CONFERENCE ROOM for the purpose of getting the NERC Guide 4 in shape for the Operating Committee's formal action and presentation and recommendation on format., The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERAT- ING COMMITTEE WILL BE ON WEDNESDAY,SEPTEMBER 11,1985 at 9:00 A.M. IN THE MAIN CONFERENCE ROOM OF MUNICIPAL LIGHT AND POWER AT 1200 EAST FIRST AVENUE,ANCHORAGE,ALASKA. Marvin Riddle motioned for the meeting to adjourn,John Marshall seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 11:55 a.m. Respectively submitted, Nyt d-bow Afzal H.Khan -Secretary Alaska Intertie Operating Committee Attachments: 1.September meeting Agenda. 2.Minutes from August 13,1985 SCADA/METERING/COMMUNICATIONS Subcommittee meeting. 3.Minutes from Reserves/Load Shedding Subcommittee meeting. 9894/410 ALASKA INTERTIE OPERATING COMMITTEE AGENDA- WEDNESDAY,AUGUST 14,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A.SCADA/Metering/Communications Subcommittee B. Dispatch/Scheduling Subcommittee C. Reserves/Loadshed D.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.SCADA/Metering/Communications C.Dispatch/Scheduling D.Reserves/Loadshed E.Operating Procedures F.University of Alaska,Fairbanks-Dynamic Stability Study G.Others VII.Formal Operating Committee action/recommendation VIII .Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light and Power Main Conference Room 1200 East First Avenue Anchorage,Alaska(907)279-7671 9894/410 ALASKA INTERTIE OPERATING COMMITTEE -AGENDA- WEDNESDAY,SEPTEMBER 11,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A. SCADA/Metering/Communications Subcommittee B.Dispatch/Scheduling SubcommitteeC.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.SCADA/Metering/Communications C.Dispatch/Scheduling D.Operating Procedures E.Operating Committee Budget F.University of Alaska,Fairbanks-Dynamic Stability Study G.Others VII.Formal Operating Committee action/recommendation VIII.Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light and Power Main Conference Room 1200 East First Avenue Anchorage,Alaska (907)279-7671 9894/410 /Warere le S-1h-BG MINUTES SCADA/Metering Subcommittee Meeting Dates 8-13-85 Time:9:90 A.M. Place:Chugach Electric Assoc. Attendence Robert Orr GVEA Dan Rogers CEA Vance Cordell CEA John Cooley AML&P James Hall MEA Marvin Riddle GVEA Doug Hall AML&P Robert Day AML&P Afzal Khan APA Ray Duncan CEA Chairman Bob Orr called the meeting to order.First item on agenda was the Data Link update. Data Link Update New hardware installed at AML&P.Communications software has been installed.The system was tested by splitting the two CPU's,tying together with DECNET,then testing their system locally.Divcom has installed 9699 baud modems at AML&P. \GuEa AML&P would like to connect their modems),to loop them and check their system locally.They would need usKxto tie the modems together for this testing.On September 15th SCI would be ready for cooperative testing.; Bob Orr updated the subcommittee on GVEA comments to the AML&P/GVEA cooperative Test Plan for the data link.AML&P is basically ready for cooperative testing,but need three weeks notice for SCI. GVEA -Divcom has installed dual 96900 baud channels.Watts line has been ordered between LGS and GVEA.Its due to be installed August 21,1985.Modem has been provided by LGS to connect. GVEA has ordered DECNET from DEC and will install it.GVEA has requested LGS to provide field support for implementation of the data link. Test procedures need to be finalized and scheduled.It appears that September 15th is a more realistic date.A joint schedule needs to be implemented between GVEA &AML&P to assure that proper coordination occurs between the two vendors.Attached is the proposed testing schedule. SCADA/Metering Minutes Page 2 CEA reported SCADA is up and all generation sites are operating approximately 12-15 RTU's.They are negotiating with APA on SCADA Data Link Agreement.CEA has ordered hardware and DECNET with license to start implementing data link to AML&P.Software development will not start until contract is negotiated with APA. Still expect implementation around 6-1-86. Metering Requirements Bob Orr pointed out to the subcommittee that the Operating Committee had already adopted metering standards on 8-10-83 for the Alaska Intertie.° : Attached is the document for the Intertie metering requirements. These Intertie metering requirements were previously adopted by the Operating Committee. All points used for Intertie transactions are required to have this metering standard.It is recommended this metering be installed atallothercriticalties(where any utility interties). Set Standards for Revenue Metering Sealing,Testing and Etc. Set standards for revenue metering,checking,sealings,calibration; categories listed below: 1.Testing Interval 8.Comparison of register readings to remote pulse 2.Sealing counts accuracy. 3.Advance notice for testing.9.Annual data review by Operating Committee. 4.Calibration 1g.Monthly removal of demand 5.CT/PT accuracy -ratio testing bubble memory modules. 6.Remote versus local accuracy.ili.Responsibility of above categories. 7.Instant versus pulse counter versus register, monthly readings accuracy. Everyone is to review these categories with their in-house staff as well as review the Intertie Agreements relative to this subject and be prepared to discuss this at the next subcommittee meeting. Robert Orr Chairman 'LANDIS &GYR ITEM #2 eae acrrvrre 'wee ane ceateact). Pema Fe wee Fee e®eee Feaea®eave ®aes %@ Covears 30Cusenra Tareeracesruucrrcess Soec rercarziIes Stereacee oF weet ets Steveneas oF veces BALI vEaT 3e e e vas-oee etcuey STUOT cz wf Test pram JEVELSSaLET 23 T2st sese rues OlveLcoesar TEST SescraGes FELT vEeRy CCeauatcatrem Lavse SRPOLLIENTATICN ecuTn an Vest ptae CULIVELe Commustcarrom Large €22 eerrtcarzom Lares 32 Soevuaele OFSTCH SacuREeTs DaLIveRe CoRarTD SoeusCarcas Caves Teecenstatatroa GvEA ©LSS COMmuNrCaTisssRINECORTATICHAL(ovER) SmTeQnar TESTIVCs SuTTszatssea ces LCS ©32 Sommunicatrces Cina SPeCarismay Cove? Cesecaartee TEsTiass smveczatsos 697649 Pacrsae accrovance ew DOLUCRRTATSCm CLeanUe tas TetTarcetios ana users SUISE Sactvaeev CoRarT) FINAL SortvaRe ass TlIOW JELIesee eteas pee _eoure ane OCCURERTATION OILEVESY DaTTS QSTIMATED BaPrULeCSs2LAPSEO WEEKS OOSSISRZ ELTINOED DATES SOF tnowns LU nav | sua oss tie °sew ore 8 |t S ' e oe Face Meee & 0,£.LACITIAL t sot fo, °e od e ° ewree of 4 °°e e e e em =9 a e °e e °e x | . °°°° { [39 |Cera F®*ere*®*vneea%®ecee%Fevael®*eovne*eens Pana ae®ane *®wae q 't 'aus iid ocr eov ec| Lis 12 MONTHLY SOOKIINATICASSCHEOULE BSITETREMT MELTING wIte SC C38G Tevesocay OF Tale SOUTH) Figure 7.0-1 Data Link Development Milestones 033-0004 04/16/85 sy1) 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 mustbelocatedatthetiepointoftheparticipanttothegrid.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 voltagemeterandsyncronizinglightindicatorsforeachside ofthebreaker;360°synce-scope.The sync-scope selector switch shall supervise breaker local "close"commands. All local and remote breaker "close”commands shall besupervisedbyasyncro-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 METERINGA.CLASS RequineD (0°72 Accuracy) TC.WH VARH >>-->-POWERFLOWa.GRID YN i DEMAND RECORDER .a _------>DATA LINK TO ARE CONTROL CENTERIJALLTRANDUCERSTOHAVE.2S°ACCURACY MINIMUM 2Q)ALL METERS TO HAVE 1%ACCURACY S)ALL METERS TO HAVE DETENTSLL |mare AUG.8,1983 TYPICAL REVENUE METERING FOR TAPS OFF THE INTERTIE 1)ALL TRANSDUCERS TO HAVE .25%ZACCURACY MINIMUM 2)ALL METERS TO HAVE 1%ACCURACY 3)WATTHOUR AND VARHOUR OEMAND LOCALLY RECORDED 4)ALL METERS TO HAVE DETENTS © POWER FLOW DISTRIBUTIONloneBUSLa1 _CT *PT METERINGMETERINGCLASSREQUIRED , REQUIRED (0.3 Accuracy)W 1(.03 ae <(1.2 Accuracy on&.Douglas Tap is okuJVARzZAo)OG=, ST. \ RTU 1 | VY Vv | Lo->DATA LINK TO AREADEMANDaCONTROLCENTERRECORDER I ANG.B.198% CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska August 13,1985 RESERVES AND LOAD SHEDDING SUB-COMMITTEE 9:00 a.m.,August 13,1985 NAME COMPANY TELEPHONE. John Cooley ML&P 279-7671 Bob Day ML&P 279-7671 Ray Duncan CEA 564-0789 Doug Hall ML&P 279-7671 Afzal Khan , APA *276-0001 Robert Orr GVEA 452-1151 Marvin Riddle GVEA 452-1151 The meeting convened at 11:15 a.m.August 13,1985.TheSub-Committee recommended the following changes be made to theUnderfrequencyLoadRetentionPlan-Alaska Intertie: 1.Insert:Alaska Intertie opens @Healy @ 59.0 HZ (between step 4 and step 5)time cycle delay -20. 2.Insert:GVEA-FMUS Intertie at Zehnder -58.3 HZ (between step 9 and step 10)time delay -20 cycles. 3.Add peak load information on 2nd sheet =total =692.8 MW. 79.4 MW....GVEA 29.0 MW....FMUS 227.0 MW....CEA 100.0 MW....MEA 78.0 MW....HEA 179.4 MW....AMLP RLD:hll T:I 8 ,Page1of2 UNDERFREQUENCYLOADRETENTIONPLAN-ALASKA INTERTIECENTRALALASKARAILBELTUTILITIESJuly1985MWe, B.W.89 -Time Load Load Percent Percent Cumilative Cumulatis- Frequency Delay Shed Remain Shed Remain Load Shed Load Sh Step Utility (Hz)(Cycles)Qh)(My)*)(2)(2)CH) 1 Golden Valley (GVEA)59.3 10 9.4 70.0 11.8 88.2 11.8 9.4SYSTEMTa684.0 1.4 98.6 1.4 9.4 2 Chugach (CEA)59.2 3 29.9 197.1 13.2 86.8 13.2 29.9 Anchorage Municipal(AMLSP)3 20.1 159.3 11.2 88.5 11,2 20.1 Golden Valley (GVEA)10 6.5 63.5 8.2 80.5 20.0 15.9 SYSTEM 56.5 627.5 8.1 90.5 9.5 65.9 3 Golden Valley (GVEA)59.1 10 7.8 55.7 9.8 70.2 29.8 23.7 Fairbanks (FMUS)4.1 24.9 14,1 85.9 14,1 4.1 SYSTEM oe)615.6 1.7 88.8 11.2 77.8 4 Matanuska (MEA)59.0 3 18.3 81.7 18.3 81.7 18.3 18.3 Homer (HEA)3 11.6 66.4 14.9 84.7 14,9 11.6 Golden Valley (GVEA)10 11.3 44.4 14.2 55.9 44.1 35.0 SYSTEM a1.2 574.4 5.9 82.8 17.2 119.0 5 Alaska Intertie at Healy 59.0 20 6 Golden Valley (GVEA)58.9 10 9.4 35.0 11.8 44,1 .55.9 44.4 SYSTEM Be 565.0 1.4 81.5 18.5 128.4 7 Gugach (CEA)58.8 3 28.9 168.2 12.7 74.1 25.9 58.8 3 21,1 138.2 11,7 76.8 22.9 41.2 Golden Valley (GVEA)10 10.2 24.8 12.8 31.2 68.8 54.6 Fairbanks (FMUS)10 10.6 14.3 36.6 49.3 50.7 14.7 SYSTEM 70.8 494.2 10.2 721.3 28.7 199.2 UNDERFREQUENCYLOADRETENTIONPLAN-ALASKA INTERTIECENTRALALASKA'RAILBELT UTILITIES , Page2of2 July 1985 Time Load Load Percent Percent Cumilative QmulativeFrequencyDelayShedRemainShedRemainLoadShedLoadShedStep;Utility (Hz)(Cycles)(Mi)(MA)(2)(2)(%)(MA) 8 Golden Valley (GVEA)58.7 10 12.9 11.9 16.2 15.0 85.0 67.5 Fairbanks (FMUS)10 3.5 10.8 8.6 37.2 62.8 18.2 SYSTEM 16.4 477.8 2.4 68.9 31.1 215.6 9 Fairbanks (FMUS)58.6 10 3.3 7.5 11.4 25.9 74,1 21.5SYSTEM3.3 474.5 0.5 68.4 31.6 218.9 10 Ctugach (CEA)58.5 3 65.6 102.6 28.9 45.2 54.8 124.4AMLAP325.0 113.2 13.9 62.9 36.8 66.2 Matarmska (MEA)3 18.3 63.4 18,3 63.4 36.7 23.2 Homer (HEA)3 11.6 54.8 14,9 70.3 29.7 23.2SYSTEM120-5 354.0 17.4 51.1 48.9 339.4 h Fairbanks (FMUS)-58.3 20 Golden Valley Tie 12 Chugach (CEA)58.2 3 54.0 48.6 23.8 21.4 78.6 178.4 Matanuska (MEA)3 30.5 32.9 30.5 32.9 67.1 67.1 Homer (HEA)3 23.2 31.6 29.7 40.5 59.5 46.4SYSTEM107.7 246.3 15.5 35.5 64.5 447.1 13 Cugach-AML&P Tie at : Plant 2 57.7 99 CEA/MEA Tie at Teeland 57.7 15 CEA/HEA Tie at QuartzCreek 57.7 30 (Seward remains on Chugach's System) NOTE:All loads are based on latest projections for Winter Peak 1985/86:Ctwgach Electric (incl.Seward)227 MW Anchorage Mmicipal Light &Power 180 MI Homer Electric 78 «MW Matanuska Electric 100 MI Golden Valley Electric 79.4 Mi C2/11¥Fairbanks Municipal 29 MW Page 1 of 2 UNDERFREQUENCY LOAD RETENTION PLAN -ALASKA INTERTIECENTRALALASKARAILBELTUTILITIES July 1985 Time Load Load Percent Percent Cumulative Cumulative Frequency .Delay Shed Remain Shed Remain Load Shed Load Shed Step Utility (Hz)(Cycles)(MW)(MW)(2)(2)(2)(MW) 1 Golden Valley (GVEA)59.3 10 9.4 70.0 11.8 88.2 11.8 9.4 SYSTEM 5.4 684.0 1.4 98.6 1.4 9.4 2 Chugach (CEA)59.2 3 29.9 197.1 13.2 86.8 13.2 29.9 Anchorage Municipal(AML&P)3 20.1 159.3 11.2 88.5 11.2 20.1 Golden Valley (GVEA)10 6.5 63.5 8.2 80.5 20.0 15.9 -SYSTEM 56.5 627.5 8.1 90.5 9.5 65.9 3 Golden Valley (GVEA)59.1 10 7.8 55.7 9.8 70.2 29.8 23.7 Fairbanks (FMUS)4.1 24.9 14.1 85.9 14.1 4,1 SYSTEM IT9 615.6 1.7 88.8 11.2 77.8 4 Matanuska (MEA)59.0 3 18.3 81.7 18.3 81.7 18.3 18.3 Homer (HEA)3 11.6 66.4 14.9 84.7 14.9 11.6 Golden Valley (GVEA)10 11.3 44.4 14,2 55.9 44,1 35.0 SYSTEM 41.2 574.4 5.9 82.8 17.2 119.0 5 Alaska Intertie at Healy 59.0 20 | 6 Golden Valley (GVEA)58.9 10 9.4 35.0 11.8 44,1 55.9 444 SYSTEM 5.4 565.0 1.4 81.5 18.5 128.4 7 Chugach (CEA)58.8 3 28.9 168.2 12.7 74,1 25.9 58.8 AML&P 3 21.1 138.2 11.7 76.8 22.9 41.2 Golden Valley (GVEA)10 10.2 24.8 12.8 31.2 68.8 54.6 Fairbanks (FMUS)10 10.6 14.3 36.6 49.3 50.7 14.7SYSTEM70.8 494.2 10.2 71.3 28.7 199.2 Step 10 11 12 13 Utility Golden Valley (GVEA) Fairbanks (FMUS) SYSTEM Fairbanks (FMUS) SYSTEM Chugach (CEA) AML&P Matanuska (MEA) Homer (HEA) SYSTEM Fairbanks (FMUS)- UNDERFREQUENCY LOAD RETENTION PLAN -ALASKA INTERTIE CENTRAL ALASKA RAILBELT UTILITIES 58.6 58.5 58.3 Golden Valley Tie -Z2/rdler Chugach (CEA) Matanuska (MEA) Homer (HEA) SYSTEM Chugach-AML&P Tie at Plant 2 CEA/MEA Tie at Teeland CEA/HEA Tie at Quartz Creek (Seward remains on Chugach's System) 58.2 57. 57. 57.7 boLoWoUo20 WoLoLo99 15 30 July NOTE:All loads are based on latest projections for Winter Peak 1985/86: C2/11Y 1985 Load PercentRemainShed (MW)(2) 11.9 16.2 10.8 8.6 477.8 2.4 7.5 11.4 474.5 0.5 102.6 28.9 113.2 13.9 63.4 18.3 54.8 14.9 354.0 17.4 48.6 23.8 32.9 30.5 31.6 29.7 246.3 15.5 Chugach Electric (incl.Seward) Percent Remain (2) 15. 37. 68. Anchorage Municipal Light &Power Homer Electric Matanuska Electric Golden Valley Electric Fairbanks Municipal HWEONFOWNOe°°eeMmNnNwo&Cumulative Load Shed MI Mw MW MW MW ()fon)Wen.wn>eeeeeee@won ICOaneOOPage 2 of 2 79.4 Mi-eapeck 44 MINUTES SCADA/Metering Subcommittee Meeting Date:8-13-85 Time:9:08 A.M. Place:Chugach Electric Assoc. Attendence Robert Orr GVEA Dan Rogers CEA Vance Cordell CEA John Cooley AML&P James Hall MEA Marvin Riddle GVEA Doug Hall AML&P Robert Day AML&P Afzal Khan APA Ray Duncan CEA Chairman Bob Orr called the meeting to order.First item on agenda was the Data Link update. Data Link Update New hardware installed at AML&P.Communications software has been installed.The system was tested by splitting the two CPU's,tying together:with DECNET,then testing their system locally.Divcom has installed 9699 baud modems at AML&P.at thei?AML&P would like to "TheeSe thei odems,to loop them and checktheirsystemlocally.They”would "EBs tie the modems togetherforthistesting.On September 15th SCI would be ready for cooperative testing. Bob Orr updated the subcommittee on GVEA comments to the AML&P/GVEA cooperative Test Plan for the data link.AML&P is basically ready for cooperative testing,but need three weeks notice for SCI. GVEA -Divcom has installed dual 9688 baud channels.Watfs line hasbeenorderedbetweenLGSandGVEA.Its due to be instdlied August 21,1985.Modem has been provided by LGS to connect. GVEA has'ordered DECNET from DEC and will install it.GVEA has requested LGS to provide field support for implementation of the data link. Test procedures need to be finalized and scheduled.It appears that September 15th is a more realistic date.A joint schedule needs to be implemented between GVEA &AML&P to assure that proper coordination occurs between the two vendors.Attached is the proposed testing schedule. SCADA/Metering Minutes Page 2 CEA reported SCADA is up and all generation sites are operating approximately 12-15 RTU's.They are negotiating with APA on SCADA Data Link Agreement.CEA has ordered hardware and DECNET with license to start implementing data link to AMLE&P.Software development will not start until contract is negotiated with APA. Still expect implementation around 6-1-86. Metering Requirements Bob Orr pointed out to the subcommittee that the Operating Committee had already adopted metering standards on 8-19-83 for the AlaskareerEhlem-/Omw fy /sst otra /reseleTi cn -Attached is the document for the Intertie metering requirements. These Intertie metering requirements were previously adopted by the Operating Committee. All points used for Intertie transactions are required to have this metering standard.It is recommended this metering be installed at all other critical ties (where any utility interties). Set Standards for Revenue Metering Sealing,Testing and Etc. Set standards for revenue metering,checking,sealings,calibration; categories listed below: 1.Testing Interval 8.Comparison of register readings to remote pulse 2.Sealing counts accuracy. 3.Advance notice for testing.9.Annual data review by Operating Committee. 4.Calibration 18.Monthly removal of demand 5.CT/PT accuracy -ratio testing bubble memory modules. 6.Remote versus local accuracy.11.Responsibility of above categories. 7.j%Instant versus pulse counter versus register, monthly readings accuracy. Everyone is to review these categories with their in-house staff as well as review the Intertie Agreements relative to this subject and be prepared to discuss this at the next subcommittee meeting. Robert Orr Chairman UC .:os [LANDIS &GYR):ITEM #2 eoure one see some m mam Pn Si ocr wov erecostescty.t t a t 'i $eeeas -Cem e Mame eee Feee MP wwe Meee Fone Fae ®eee eve &acrrerty es , tateeeacespumcrrcess fSectrrcatros>.ot STavesen'cy vee |tT)f |STaveneas oF wore SELIVERT 3e e °®e cf e °eo e fd evas-rop CECeey STUDY =(23 wsTestptawMevELosatEyY=623 of | Cevear?\T2s0 pas CeLivenr 7eeeo eo e cr)oe e e ConmuntCarrom Large wh)f :2estce ¢2> avoctcarzom Lares ralesPyiets]«3?|SO°Tuaa!OFSTCR DSUNENTS rsOELTvERe(ORAPTD e e e e cd C7 rd e e eoTESTresceoueseAfOLVILCPefeT2) TEST PrecrouRs SeLrvERT Pr)eo cd e e eo cd °cd o 7 Ceeavercatrom tarze 9.Le fLaPLCetnTation(3?Vv aomurcatcom taven 0 _LPARTIA Lwarcentataticnco o e e e °e oe e »eGYTA=USS Cohnunccarisas er *000 3 RING CHRTATICmaL (SVE TMTECwAL TESTIVGs [|sutesastsoe TS) o e eo e e o e e °°e LCS ©32 Commumscariens i.re|RINK SPECATI SHAR Cove? Ccoperarree TESTINGs |O.ncnl>==°<0tereczatsom(T3273) o °e e e cd e Cd °e rPacToaeaccrrancscn2 DOLueEATETsCM SutamuP =629 9.29eetde°°e e e TwSTarcattom ans usse's 33GUIDESULTVERT(3RaPTD FLwAL torrvargs ag5 3DOCuUREmTsttOmDELIVERY: etizs Sn a SP |SPoattt1t 't t 1scutnCoureapgaaysuesun|auc stp ocr aoe dec wmobhe LICLTHG eoocee'-, eo ©oKCComesTarrom OfttvEeY DATES Tub 18 C2?©ESTIMATED mawmeSECS/2L ARSED WEEKSorSoeo©=PSSSIBLE EXT2UOZO DATES °BOT SnowRs 1)MONTHLY SOORILMATICM/SCHEOULE RIZUSTRENT MEETING WITH SC C320 Tauesoat OF TACH SoUuTH) Figure 7.0-1 Data Link Development Milestones 033-0004 04/16/85 1) 2) ae /)ZY 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 Figure l or Figure 2 depending on the facility.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 bus 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 shallconsistofthefollowingasaminimum:analog voltagemeterandsyncronizinglightindicatorsforeachside 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. >9-ceeeee| TYPICAL REVENUE METERING 'FOR INTERCONNECTED OPERATION INTERCONNECT. PT METERING'AN CLASS REQUIRED (0.3 Accuracy) JC WH _VARH |DIG |]7 bf o---» oN],WM ad . z W \_/VAR:YOOoO Qa \ y Vv YY zZ RTU J nN - GRID N \ DEMAND !, RECORDER ee 5 DATA LINK TO AREZ CONTROL CENTERIJALLTRANOUCERSTOHAVE.25°ACCURACY MINIMUM ALL METERS TO HAVE 1%ACCURACY S)ALL METERS TO HAVE DETENTS Ia.AUG 8,1963 TYPICAL REVENUE METERING FOR TAPS OFF THE INTERTIE POWER FLOW Ss, >3c b |],CT PT METERING -|METERING CLASS REQUIRED (0.3 Accuracy)CLASS REQUIRED (.03 Accur INTERTIERTUV -aaexonY WV DEMAND RECORDER L--> 1)ALL TRANSDUCERS TO HAVE .25%ACCURACY MINIMUM 2)ALL METERS TO HAVE 1%ACCURACY 3)WATTHOUR AND VARHOUR DEMAND LOCALLY RECORDED 4)ALL METERS TO HAVE DETENTS- DISTRIBUTION BUS (1.2 Accuracy on Douglas Tap is ok) DATA LINK TO AREA CONTROL CENTER ANG.RA.198% 20 JEM®- ELECTRONIC JOULE METERS Patents 3794917,3975682,3971979,3976942 DESCRIPTION The JEM brand Electronic Joule Meter presented by Scientific Columbus is the first all solid-state meter for electrical energy measurement.The JEM is inherently superior to induction-type meters in accuracy and stability and offers extraordinarily low influences of voltage vari- ations,power factor,burden,temperature,frequency,har-monics,and external magnetic fields.Its unique construc- tion allows combinations of several functions in one small package such as watt/watthour,var/varhour,volt/volthour, and ampere/amperehours.” The JEM has become widely accepted by electric power utilities for revenue metering,interchange metering, statistical metering,substation metering,and Time-of-Day metering.In addition to the higher accuracy and stability, the JEM is less expensive for many multifunction applica- tions.Additional cost savings are realized by reduced instal- lation costs,reduced space requirements,longer recalibra- tion intervals due to high stability,and the built-in analog outputs (which can eliminate the need for a separate trans- ducer). New JEM functions and features include electronic reg-isters (with non-volatile memory),demand and COED (caded output electronic display)see page 22.The first arithmetic RMS Voit Ampere (VA)is also available.Other developments are constantly in progress to maintain Scien- tific Columbus'position as the leaders in solid-state meter- ing and to solidify our commitment to electric power utilities and related industries. @ All solid-state meters e =0.1%of Reading Accuracy@Excellentlong-term stability¢Built-in registers (Electronic or Electromechanical)@ Solid-state KYZ outputs plus analog outputs@Approvedforrevenuemetering =" e Multifunction capability (up to 4 functions) TYPES MODEL NUMBERS (JEM -) 1Element 2 Element 2-1/2 Element 3 Element Watthour (Unidirectional)102 104 103 Varhour (Unidirectional)112 4 413 Voithour 121 121 (1 element) Volthour -Expanded Scale 121-09 121-09 (1 element) =Watthour (Bidirectional)202 204 203 =Varhour (Bidirectional, fead/lag)}212 214 213 Watthour/Qhour 302 304 303 Watthour/Varhour (Laq}312 314 413 =Watthour/Var {Analog only)322 224 323 Watt/Var (Analog onty)R2 334 333 Watthour/Var (Analog only)342 344 «343 Watthour/VolthourQhour §02 504 503 Walthour/Volthour {expanded scate)/Ohour $02-09 $04-09 §03-09 Watthour/V?hour Qhour $12 514 $13 Watthour/V¥2hour/Varhour $22 S24 §23 =Watthaur =Varhour 602 604 ©603 =Watthour;Qhour 612 614 613 Watthour=Varhour 622 624 623 Amperenour 131 132 133 Ampere (Analog only)141 142 143 Ampere*Hour 161 162 163 Watthour/Volt-Ampere hour 351 32 354 353 Volt-Ampere hour 182 184 183 Watthaur/Varhour (Lead)362 364 363 Watthour:Voit (Anaiag oniy)402 403 =Wanhour;Voit (Analog oniy}412 433 Watihour Ampere (Analog only)422 423 2 Watthour/Ampere (Analog onty)432 433 WatthourVar/Valt . (Anaiog only Var =Voit}442 443 =WatthourVar/Volt (Anaiog only Var -Vott)452 453 Watthour/Voit/Ampere (Analog only Voit Current)462 463 =Watthour/Voit/Ampere (Analog only Voit Current)472 473 Watthour/Voithour/ Voit-Ampere hour -$32 §34 $33 =Watthour/Voit-Ampere hour §32 .634 633 =Watthour/Ohour/Voitage Squared Hour 642 644 643 Volt-Ampere haur/Qhour 2 374 373 Watthour/Volthour/=Varhour 652 654 653 Note:Other modeis available -consuit factory. JEM Options 02 10 Amp Current Cais -E "Electronic Registers (with JEM): @ 7.5 Amp Current Coils F Surtace Mount (Front connection) 04 2.5 Amp Current Cons P Panel Mount (Sem ttush) 05 1.0 Amp Current Cais W Waist Mount 06 480 Volt Voltage Col T Time Pulse Output O7 «240 Volt Voltage Coils Us Serial 1/0 Intertace (ASCII) G8 69 Volt Voltage Coils X Offset (Pulse Onty) 09 Expanded Scale Voitnours As Time Syne input 10 Register Divider 10:1 Vo Quadrant Voltamoere Incication 11 Register Divider 100:1 --2 Dual Output Sold State Contact 1 function 12 Register Oiwider 200°1 ZZ Dual Output Sod State Contact Sfunction B Surface Mount (back connection) C Canacian (OCCA Approvea) O Demand {inctudes electrome register) O00 Oemand on 2nd tuncuon Note:To clearly sdentity each model use "JEM then tne model and number followed by a dash and then the option number tsted adove.Ail mogels should show option F,P or 8.if more tnan one option is Fequested,add another dasn ang then the 2nd option.Not ail options are avarlabie with every model due to Space or other limitations.Check with factory if 4 would appear that your option will use an excessive amount of additianal termunaix Add aotion onces into kst prices Detore taking quantity drscounts = u @ "toysttm SPECIFICATIONS 'tormal Operating Conditions Power Input Fntential Input "werent inout ower Factor Auathary Power amorent Temperature Frequency Helative Humidity "aputs Current Input Burden Overload Potential Input Burden Overload Auxiliary Power Burden Outputs Analog Output Pulse Outputs Solid-State Pulse Output Electronic Display (Optional) 600 W/element (2 element-1200,2% element-1800,3 element-1800)where applicable 75 to 135 V,120 V nominal 0-10 A,5 A nominal 0 Lag -Unity -0 Lead85-135 Vac,60 Hz =10% 2e7Cc=+SC 58 to 62 Hz %to 95% Inputs are barrier-type terminal blocks with 10-32 screw terminals.Contacts are nickel/tin plated brass. O -10 amperes load range 0.2 VA per element at 5 A nominal 15 A maximum continuous 12¢maximum of 80,000 A's 120 V nominal,75 -135 Vac normal oo- erating range.and 20 -150 V extended operating range. 0.05 VA at 120 V/element 250 V continuous 5 VA maximum,85 to 135 Vac con- tinuous Outputs are provided on rear barrier terminal blocks with 8-32 screw contacts. 1.2 mA de at nominal rated input,10 Vdc maximum compliance. The analog output can be bipolar,revers- ing polarity for reverse input conditions where applicable. Pulse outputs ase provided proportional to the metered function with a wide range of pulse rates available.Pulse outputs are normally the same pulse rate as the reg-isters.Pulse output connections are referenced as "K","Y","Z"terminals. The pulse output is a three wire,Form Cconfiguration,NPN transistor pair.Each-pulse output is defined as the change ofconductionstate(ON or OFF)of both tran-sistors.The solid-state output is photo- isolated from the internal circuits and has the following limitations:- Maximum Ratings Vce (OFF statemax.volts)200Vdc or peak ac Vcesat (ON statevoltagedrop)2.5V @30mAICMAX(Transistor current)50 mA dc The electromechanicai counter(s)(regis-ters)may be replaced with a micropro-cessor controlled 6-digit LED display.Theregistersareinterchangeable.The displaymaybeoperatedinarollingmodeora hold mode which is push-button con-trotled.In the rolling mode,all functionsonagivenJEMareconsecutivelydis-played for 4 seconds each in a continuingcycle.in the hold mode,any function maybeobservedindefinitely.LED's indicatewhichfunctionisbeingdisplayed.Thememoryisnon-voiatile even with com- plete power failure. Demand Option KVA Options Registers Rate Indicators Potential Indicators The microprocessor controlled electronic display includes an optional demand fea- ture.Fixed 15,30,or 60 minute demand intervats ora sliding window capability are available.The demand feature may beaddedtoWatthourorVarhourorVAhour models.The demand is monitored duringeachdemandintervalandthenautomat- ically reset at the beginning of a new inter-val.The highest demand is stored untilitisexceeded.at which time the new demand is stored.The peak demand is displayed on the Electronic Dispiay as described above.The memory is non-volatile,evenwithcompletepowerfailure.This dataloss protection is accomplished by use of a non-rechargeabie battery with guaranteed10yearlife. Arithmetic Volt-Ampere (VA)&Volt- Ampere hours are available.See page 22. 6-digit registers are electro-mechanical counters with individually compensabdledigits.Operating life expectancy is in ex-cess of 60 million counts.Maximum counts speed is 4 counts/second or about 15.000 counts/hour.Normally register units are the same as pulse outputs.how- ever,register ratios for 1/10 and 1/100 are available options. Flashing red LED's show relative input.These may be set up to operate up to 16 times faster than pulse outputs for lightloadindication. LED's display presence of potential inputforeachelement. Accuracy Specifications,Pulse Outputs NOTE:%CL -output at maximum rated load current,nominal potential. Accuracy withinNormalOperatingConditions Watthour /Q-hour Var Hour Volt Hour & Volt?Hour Temperature influence Extended Potential Operating Range Zero Load Operation Outputs Starting External MagneticField (0.1%Reading +0.01%CL) (0.15%Reading +0.01%CL) *(0.15%Reading +0.05%CL)From 59.98 to 60.02 Hz +0.25%ReadingFrom60to150Voits 0.005%/*°C for Watthour and Q hour. 0.009%/°C for Varhour or Volthour maximum over operating range trom20Cto+77C. Additional error maximum of 0.1%from 20 to 75 V and 135 to 150 V.ItItThe unit will not produce pulses at registers or pulse outputs with zero input. Minimum of 0.02%of rated input is re- quired to produce normal meter opera-tion.' Less than 0.01%RO with 100 ampere- turns produced by a Straight conductor 6' long carrying a current of the same fre- quency and phase as the applied voltageandpositionedinanydirection10°from the center of the meter. 21 JEM?SPECIFICATIONS,TyPE iv PRODUCT CONTINUED Analog OutputsAccuracywithin Norma!Operating ConditionsWatt =(0.12%Reading +0.02%CL) Q,VAR,Volt &Volt?Maximum error in addition to Pulse Out- put Specification +0.03%CL Ripple 0.25%CL peak maximum Response Time 0.4 second to 99%of final value Rioad X lout 10 Vde maximum (condition for maximum output) Example: Rioag=4.16 kilonms max,at.lout=2.4 mA Load Resistance Surge Withstand No damage to unit or extraneous outputs shall occur when subjected to a test wave of 1.5 MHz nominal frequency with a 2500voitcrestvalueforthefirsthalfcyciepeak.and decaying to $0°%of the crest vaiue innotiessthan5microseconds.The test wave is applied at a repetitive rate of not less than 50 tests per second for a period of not less than 2.0 seconds.Reference ANS!C37.90a. Pulse rates are determined by selecting one of five resistor networks and one of seven binary divider taps giving a total range of 128:1. Calibration Ranges (This would be the condition of 2-element eeys ca ons See page 47 watt output operating at 1200 watt/ele-'' ment input)Weight 10 pounds,10 ounces,typical Isolation Current,Potential.and Auxiliary Power Mountin Flush (panel)mountInputsinputsratedat2500Vrmsfor1minute.9 Svan te wall mount -front or back- Outputs "K","Y""2"pulse outputs and analog Fee eee Mountoutputstocaseare1000Vrms.Additional mounting hardware supplied Note:Analog outputs shail not be subject when specified. to differential dielectric test. ELECTRONIC JOULE METER WITH VOLT AMPERE CAPABILITY DESCRIPTION The JEM with VA capability is the first solid state meterWith instan- JEM/CO °taneous arithmetic RMS volt ampere measuring capability.There is°no phase angle influence whatsoever.One JEM ¢an provide kVAhusageasweilaspeakandpresentVAdemandalongwithother DESCRIPTION metering functions. The JEM with coded output and electronic display can be read remotely by bidirectional communication links.tts ASCIl coded serial Output is compatible with most 7 bit ASCII coding systems.The electronic display allows the meter to be read locally. ADVANTAGES @ Data communication links need to be established only when readings are desired.Loss of data will not Occur with power outages or communication link failure. e@ Rate structures such as time of day,peak demand,pow or other complex structures can be changed without expensiveandcomplicatedfieldtripstothemeterforprogramming: @ Meter readers may not want to carry automatic meter reading equipment to the field to read complicated magnetic tape re- corder replacement devices.The JEM/COED allows the meter reader to read the electronic register locally in a normal man- ner. ©Aprinter can be added on site to print all load profile informa tion. @ The JEM/COED makes possible detailed load research stddies and provides a way to read the meter often when the i expenencing peak loads. ®Because of the multifunction capability of the J as kVAh,kWh,Peak Demand,Present Deprand,and many others,the data handied by the communication link is greatly reduced. @ Automatic remote billing can be aceédmplished with the high accuracy available only in the JEM brand line.@ The COED portion of the JEM <an be added to existing JEMproductsinthefield. FEATURES e ASCit Coded Serial OutputIsolatedInterface'to 20 mA Current Loop1500VrmsIsofation 7 bit ASCIL Coding,with start bit,parity,stop bit for 10 bits/charact Meter-address pre-programmed or field programmable PpkCations:Billing,load studies,research and department ac-ef ntability of energy in industrial applications. ADVANTAGES e Reliable most accurate replacement for discontinued or an- tiquated kVA metering prodyCts.@ Existing or new kVAnN or KVA demand rates can be enforced with assurance of ade e Additional revenue WO external auto-transformers or compensators required.Not dependent on balanced phase voltages or phase angledisplacement. e in wide extremes of environmental changes and withinghasnoeffectonaccuracy.e Pulse ovtguts proportional to instantaneous VA are standard. mand can be supplied with kWh or other pact multifunction JEM. customer can also observakVAn and kVA demand on the elec- tronic display. FEATURES @ Available in 2,2-%and 3 Elemen @ Analog output:1.2 mA at 600 VA/el@Pulseoutput:Form C solid state from hour at 600 VA/element @ Accuracy:=(0.2%reading +0.05%class)ing conditions and any power factor. ment input Q6 to 26,419 pulses per aver normal operat- Applications:Enforcement of power factor penalty clauses.En- courages users to improve power factor on each phase.Consultfactoryforcompletespecificationsandavailablemodas. 22 Technical Bulletin 18146 MBR-90 | Magnetic Bubcie Recorder DESCRIPTION The Sangamo MBR-90 (Magnetic Bubble Recorder) is a solid-state recording device that directly replaces magnetic tape recorders for billing and survey applications.Utilizing non-volatile magnetic bubble memory as its recording medium,the MBR-90 provides continuous,detailed and time- synchronized records of pulse output.Resolution is increased almost three times over that previously available with magnetic tape recorders. The MBR-90 has a standard recording interval of 15 minutes.Dafa is accumulated in the recorder RAM (Random Access Memory)and written on thebubblememoryeveryfourhourswith2-channel recording and every eight hours with 1-channel recording.The writing process is extremely rapid, taking place in less than 0.2 seconds.A total pulse count is also written onto the bubble memory, providing a check against the sum of the pulses in the recorded intervais. The MBR-90 is a logical choice for applications where accuracy and reliability are of prime importance.The recorder itself has been field- tested and proven reliable in a multitude of operating conditions.Some advantages of the MBR-90 are as follows: e Simple to Operate Set-up takes less than five minutes.Changeout of modules is faster and simpler than changeout . of magnetic tapes.me e No Moving Parts All solid-state construction means high reliability and low maintenance. e Real Time and Customer [.D. These quantities are written into each module. e No External Equipment Required e Field Diagnostics ; Allows recorder functions to be tested in the field,thereby reducing down time. e Battery Test Test jacks are provided on the front panel toExternalequipmentsuchasprogrammersandconnectadigitalvoltmetertothebattery reading devices are not required for normal terminals for testing.A push button on the front recorder operation.removes line voitage from the recorder. CARY - DESIGN FEATURES Magnetic Bubble Memory Module The magnetic bubble memory used by the MBR-90iscontainedinacompactunitreferredtoasthe memory module.Each module has a storagecapacityof92Kbitsofbinarydata,corresponding to 35 days of pulse data storage capacity with 2-channe!recording or 70 days with 1-channel recording.The memory chip used is a Serial device consisting of organized magnetic domains or "bubbles”.The presence of a bubble in a "bit” position represents a (1).The absence of a bubble represents a (0).Unlike magnetic tape,a bubble module will not wear out as there are no moving parts and no known electronic or magnetic effects which limit the life of the component or the number of read/write cycles that it can perform. The module is inherently non-volatile (requires no external power source to preserve data)and maintains data integrity from -40°F to 185°F(--40°C to 85°C).Reading of and writing to thebubblememorytakesplaceattemperaturesabove 32°F (0°C).Thermistor controlled heater boards located above and below the bubble controller board maintain the bubble components at the proper temperature. Data Accuracy \The MBR-90's magnetic bubble memory is capable of accurately recording up to 4095 pulses per 15-minute interval,which is considerably greater than the 1500 pulses per 15-minute interval capacity of magnetic tape. Running Pulse Total A running pulse total from each channel is written into the magnetic bubble memory.This information is used to check the pulse counts in the recorded intervals and is equivalent to the function of the pulse register option in a magnetic tape recorder. Read-After-Write Confirmation A read-after-write check is performed each time the recorder writes to the bubble to ensure that data has been accurately transferred from RAM to the magnetic bubble memory.Every record except the removal record is checked for read-after-write errors.Should data not be read back correctly,the process is retried.If proper transfer is not verified after three tries,the data is left in the magnetic bubble memory and the entire period (four hours _with 2-channel and eight hours with 1-channel)isissignedastatusof'R",signifying a read-after-\write error.The front panel status light flashes toalertfieldpersonneltotheproblem. Error Statuses Two different errors are recognized by the MBR-90 and are statused in the recorded data:power outage (O)and read-after-write error (R).The four- hour or eight-hour period in which the error occurred is statused with the appropriate code and is noted as such when the pulse data is translated. Latching Input Electronics The MBR-90 will accept pulses from either a Form C,electronic or mechanical Poser nitiator (SPI)orfromaFormA,self-powered eleCtronic initiator. Master Time Pulse An optically isolated switch output is provided that closes for four seconds at the end of each recording interval to allow for the synchronization of external (non-MBR)equipment.It is rated 30 VDC,400 ma.with 2500 VDC (peak)isolation. PHYSICAL FEATURES Construction Solid-state construction incorporating CMOS and sliding it out.The terminal strip is located in components is used throughout the MBR-90.Six the lower half of the cabinet and is accessed boards are utilized:the mother board,two heater through a hinged door.Four conduit wiringboardsandthreeboardscontainingactiveknockoutsaresuppliedforcableentry.The batterycomponents.The MBR-90 internals are arranged so and current transformer are mounted on the lower that the two heater and three active beards piug door of the cabinet.The enclosure is painted directly into the mother board,which is placed anodized aluminum,has continuously welded vertically in the back of the cabinet.A board can seams and is designed for surface mounting inbeeasilyexchangedbyremovingthefrontpanelindoororoutdoorsettings. PROCESSOR BOARD HEATER BOARD CONTROLLER BOARD HEATER BOARD DATA AND POWER SUPPLY BOARD arOVOLTAGE SELECTOR SWITCH MOTHER BOARD TERMINAL STRIP KNOCKOUTS Q @ Status Light The status light is continuously illuminated for 45 minutes following module insertion or a power outage.Modules should not be removed while thelightison.A flashing status light indicates that a read-after-write error has occurred.In this case, the module should be certified (i.e.,data erased and checked for malfunctions)and the recorder should be checked with a diagnostic device before further data recording is attempted. |LED Display and Mode Select/Display SetButtons Identification,time and date information are set and checked on a five-digit front panel display thatcanbecycledthroughthevariousfunctionsoneat a time using the MODE SELECT button.Data displayed for date,time and 1.D.can be changed through the use of the front panel DISPLAY SET button.The LED display can be set to its visual pulse indicator mode,but it returns automatically to the hour/minute display.The display is dark only when AC power is out. ®Module Latch The module latch controls the data transfer functions of the MBR-90.Writing to the bubble cannot take place unless the latch is down,and the latch cannot be lowered unless a module is in the reader slot on the front of the recorder.The hinged front door cannot be closed until the latch is in the proper position,thus preventing field personnel from leaving the recorder without a module properly installed. wcoe Gi aoa@:@ 9:i aece SELECT % @ Battery Carryover SystemAbatterycarryoversystemhas been incorporated to maintain accurate time synchronization during power outages.An internal battery provides a seven-day minimum carryover,and clock frequency accuracy during carryover is maintained at 60 + 0.004 Hz. A sealed lead-acid,6-volt,2.5 ampere hour battery is used in the battery carryover system.It is readily accessed through the lower door of the recorder and offers several unique advantages: ®No leakage or corrosion maintenance. «No memory effects as with nicad batteries. ¢Recorder circuits are unaffected by battery removal assuming AC power is continuous. ¢Battery is rapidly float charged (constant potential)following power outages. Battery capacity can be determined by a simple open circuit voltage test of the battery terminals. Test jacks are provided on the recorder front panelQ>cercec a digital voltmeter to the batteryninals i :Aipeedaeeead1GaiaiNeendeeeAassailedLOOgagel@©mprsuigraale| @) 100 Year Clock-Calendar The MBR-80's clock is synchronized to line frequency during normal operation.A 100 year clock-calendar incorporated into the recorder keeps track of the date and automatically adjusts for leap years. Jumper-Selectable Features Jumpers are accessed through the upper pane!of the recorder.The following features are jumper- selectable: -Standard or daylight savings time. -1 or 2 channel recording operation. -50 or 60 Hz. -4channe!totalizing. Switch Selectable Voltages The MBR-90 has a 120/240/277 volt switch mounted on the mother board that allows the voltage to be properly selected by field personnel at the installation site. 2500 Volt Hi Pot and Surge Protection Each recorder is designed and tested for a 2,500 volt AC potential withstand test,consistent with electric meter standards.Metal oxide varistors protect the MBR-90 for surges through 10,000 volts (10KV).These protection features significantly reduce any electronic failures due to surges on the power system. Totalizing Function The purchaser has the option of totalizing four channels into two. TRANSLATION FEATURES The two methods described below are available to translate data obtained from the recorded modules. MBR-S0 Reader-Certifier The MBR-90 Reader-Certifier interfaces to standard Hewlett Packard translation systems (HP 1000 based).Read time for the magnetic bubble memory module is only 15 seconds,and data is supplied to the computer at speeds of up to 9600 baud. Data can be transmitted from a remote reader toa central translator via telephone lines.The same bubble can be read any number of times or the data can be outputted and stored indefinitely on magnetic tape or disc.Certification,which tests and resets the module to a zero or blank state,is done in a separate module port.A front panel light indicates the end of certification or flashes if the bubbie will not certify. Full report capabilities of the translation software can be used with data recorded on the magnetic: bubble.Translation routines are similar to those used for magnetic tape cartridges.MBR-90 data records can be made to duplicate existing output formats.For further information on interfacing this reader,contact your Sangamo representative. BMIT-90 (Bubble Memory InterrogatorTranslator)vwneyWSsRiSephoawere7aerhe:tTTTELSbeSeOTe]wady,Guy.Taamsiaron 'PeapeurRED°PGiThe BMIT-90 is a table-top,microprocessor based transiation system that works with most standard 132-character (RS232 interface)printing terminals. Under commands from the terminal,it accepts the translation program from one dedicated storage module and the fixed data for any of 154 customer installations stored in a second module.The BMIT-90 reads the pulses recorded on the field data module and calculates the desired output, sending it to the printer in any one of four fixed format reports.Where typical billing and survey data reports are required,the BMIT-90 is a highly reliable and versatile alternative to the Hewlett Packard based translation system. g PRINCIPLES OF OPERATION The MBR-90 writes to the bubble at real clock times of 0:00,4:00,8:00,12:00,16:00 and 20:00 with 2-channel recording and at 0:00,8:00 and 16:00 with 1-channel recording.The recorder waits 45 minutes after module inserticn before writing to ensure that the module reaches the correct temperature.During this 45-minute period,pulse data is accumulated in the recorder memory.At no time during normal recorder operation is pulse data lost.For example,a module is inserted and the latch is lowered.The recorder waits 45 minutes before attempting to transfer accumulated pulse data to the module.If at the end of that 45-minute period a write time has not been reached,the MBR-90 continues to accumulate pulse data until a write time occurs.If a write time is reached during the 45-minute period,however,the MBR-90 waits until the end of the next 15 minute interval after the 45 minutes and then writes to the bubble. The first block of data recorded is the insertion record.This includes ail the pulse data accumulated from when the last module was removed (or when the recorder was turned on),the time the module was inserted,and the recorder insertion total,which is a cumulative total of the pulses that the recorder had received when the last module was removed. Vhen the module is replaced at the end of its recording period (a maximum of 35 days with 2-channel recording and 70 days with 1-channel recording),the removal record is written.As the operator raises the latch to withdraw the recorded module,the MBR-90 writes this record.It includes the accumulated pulse data in its memory,arecorderremovalpulsetotalandtheexac*time at° which the module was removed.The MBR-90 again accumulates data in its memory while the operator inserts a new blank module,and the cycle begins again. The LED display on the front panel of the recorderfaceservesseveralfunctions.A five-digit recorderinstallationnumberenteredbyfieldpersonnelatiheinstallationsiteusingtheDISPLAYSETandMODESELECTbuttonsisdisplayedontheLED.This 1.D.number is written on each magneticbubblemodulethatisrecordedbytheMBR-90,and serves as a quick cross-reference when the module is read during translation.When power isfirstappliedtotherecorder,the year,month,dayoftheweek,date,and real-time hour and minute must also be entered by field personnel.Thecurrentinformationiswrittenoneachrecorded module.Another function of the LED enables field nersonnel to quickly verify correct operation of theilseinitiatorelectronics.When the LED display$Set in the incoming pulse check made,four ofthefivedisplaypositionschangeasdatapulses are received.The positions,labeled Channel A,B, C and D,alternately flash 0 and 1 as pulses are received from the initiator.=( MBR-90 DIAGNOSTICS The MBR-90 Bubble Recorder Diagnostic Module is used to verify that recorder functions are performed correctly.The diagnostic test may be used for incoming acceptance tests,periodic field inspections and for shop analysis.The diagnostic module plugs into a port located on the face of the MBR-90 and runs interactive and program-directed tests.If a malfunction is detected during a program-directed test,a diagnostic code is shown on the LED display.Along with normal troubleshooting,these tests aid in the identification of the malfunctioning board or component involved.The following are some of the advantages of the MBR-90 Diagnostics: -Simple to perform. -Takes less than five minutes to complete all checks. -Reduces down time.Recorder does not have to be brought into the shop for testing. -Allows critical recorder functions to be checked in the field. -Increases data accuracy because malfunctions are quickly diagnosed and repaired. SUMMARY - Utilizing non-volatile magnetic bubble memory as its recording medium,the MBR-90 provides continuous,detailed and time-synchronized records of pulse output.The recorder has been thoroughly fieid-tested and is proven to be simple to operate as well as reliable in a multitude of operating conditions.The MBR-90 is the logical choice for applications where accuracy and reliability are of prime importance. OrSPECIFICATIONS FOR THE MBR-90 RECORDING MEDIUM:Magnetic bubble memory in a removable module form. RECORDING CHANNELS:One or two (strap selectable),with two or four input totalizing. DEMAND INTERVAL:15 minutes. PRIMARY TIMING SOURCE:Line frequency (50 or 60 Hz). RECORDING DURATION:70 full days with single data channel input.35 full days with two data channel input (selectable). MAXIMUM INPUT PULSE CAPACITY:4095 per 15 minute interval per (totalized)output channel. ISOLATION:From line (high potential withstand level)2500 VAC RMS. POWER REQUIREMENTS:120/240/277 volt AC +10%(switch selectable),50 or 60 Hz. BATTERY CARRYOVER: Battery:6 volt,2.5 ampere hour,sealed lead-acid. Duration:7 days at -20°F to 150°F. Oscillator Accuracy:60 +0.004 Hz (0.007%). Charging Circuit:Float charged (constant potential) -temperature compensated. Low voltage shutdown protection after rated carryover. Recharge time:50%capacity in 3 hours. 80%capacity in 5 hours. 100%capacity in 24 hours. AMBIENT OPERATING TEMPERATURE:-20°F through 150 °F. AMBIENT TEMPERATURE FOR DATA RETENTION:-40°F through 185 °F. HUMIDITY:0 to 95%RH non-condensing. ENCLOSURE:Surface mountable,painted anodized aluminum,has continuously welded seams.Weather resistant with removable,hingedfrontdoorandbattery/terminal compartment.Four conduit wiring knockouts. SIZE:15”tall x 8.45”wide x 6.2”deep. @-O0/0fechnical Bulletin 487143 tt WT Tie ROTTS OTe oe Pom BMIT-90 Interrogator/Transiator Bel Kore te RI FRE Reis theTe ae Description Sangamo's BMIT-90 (Bubble Memory Interrogator/Translator)is a table-top,portable translation system for bubble memory modules recorded by the MBR-90 pulse recorder.The BMIT generates translation reports similar to those produced by a computer-based translation system at a fraction of the cost. In addition,it certifies memory modules and can copy any given module onto a blank module.The standard BMIT transtation system consists of the following elements: 1)BMIT-90 translation device. 2)Program storage bubble memory module. 3)Fixed data storage memory module. 4)KSR printer (printer with keyboard). The BMIT loads user-entered data about the customer installation from a dedicated fixed data module.The field data pulse counts are then read from the recorded bubble memory module,and caiculated output parameters are dumped to a printer in any of four fixed format reports. Principles of Operation The BMIT-90 operates with any EIA standard KSR printer,132-character with RS 232 interface. Under operator commands from the printer,the BMIT accepts first the translation program from one dedicated storage module (pre-programmed by Sangamo)and then the fixed data for the installation parameters of any one of 154 customers stored in a second dedicated module. The "ON/OFF”meter readings from a particular customer installation are entered by the operator.The "OFF”reading is stored in the fixed data module and is used as the "ON” meter reading for the next translation on that customer. A recorded field data module is inserted from the customer installation selected and the fre Te OE ee See NE ee et BM t-99TRANSLaTon operator specifies the reports to be printed.The BMIT performs the tasks and indicates the completion of each report. The BMIT is easy to operate and requires no prior knowledge of computer operations.The following basic steps perform BMIT-90 translations: 1)Load operating program from the program module. 2)Check fixed data in the fixed data module. 3)Load fixed data and enter "ON/OFF"meter readings. 4)Load data from field data module and generate reports. Zz &BB Bese A Se AoE "Design Features The BMIT is a compact yet durable translation ystem.It weighs only 20 pounds and can easily 2 transported to remote sites.Its exterioris a rugged fabricated steel housing with finished aluminum front and rear plates. Front plate features include the on/off switch,reader status light,bubble reader Opening and latch,and storage spaces for the fixed data and program modules.The status light is illuminated whenever the module in the reader slot is being read or written to.The bubble latch prevents the BMIT from reading or writing to a module until it is lowered.It also prevents a module from being removed accidentally by ''locking”'it in place.3Ris.ulianea}20TepeUceesaSererRMeneegemamee,Mt3thes,eoapesome(earunOaprehyietreeiposobone,woeesAeONeeeeereee:AllstahtBMIT-90 TRANSLATOR weeeepegemmenpeniemeeeeonseeduatradaaslabsdenebeiLieeeteedi;:'4BMIT-90 FRONT PANEL The BMIT design is based on the highly retiable MBR-90 recorder,utilizing CMOS and LSI components.Circuit functions are segregated onto individual P.C.boards.The processor board contains the micropro Sor and the I/O ports. The memory board has 14K of RAM and the bootstrap ROM.The controller board provides the interface with the bubble modules.The UART and I/O boards interface to the printer, and the power_supply board provides system power.All boards excep 1/0 board plug into Q'"mother”board,allowing easy removal.ne ROM is apermanent memory located inside the BMIT which stores the bootstrap program used for loading the operating program.The RAM stores the operating program from the program module,as well as the fixed data and rate schedule far the currant tranelatinn Tha When the translation is completed,the tixed data in RAM is replaced by the next installation's fixed data. Power requirements for the unit are 115 or 230 VAC +15%,selected by a switch located on the mother board.Power line frequency is 50/60 Hz.The unit is fuse-protected against overload and protected by meta!oxide varistors against transient voltages.It operates over a temperature range of 0°C to 50°C (32°F to 122°F)with a relative humidity of up to 95% non-condensing. The bubble module used is a palm-sized package utilizing the Tl bubble memory chip, which has a storage capacity of 92K bits of binary data.The memory chip is a serial device consisting of organized magnetic domains,or bubbles.The presence of a bubble represents a(1)the absence of a bubble a (0).Unlikemagnetictape,the bubble module will not ''wear out”as there are no mechanical moving parts and no known electronic or magnetic effects which limit the life of the component or the number of read/write cycles it can perform. Reading of the bubble module is a non- destructive process. DAAAQMAON 02/02/52 EMIT-90 TEST SANGAMON EMIT SUMMARY REFORT KEYS12345 [f=12345 ACCOUNT #INZERTION 04/25 13246 CUSTUMER NAME EXAMPLE REPORT REMCVAL 04/26 15206 INTERVAL LENGTH 15 RATE SCHEDULE #1 STATUS CK FOR FEAK MATAR METER READING ON METER READING OFF #OF METER DIALE METER NET METER MULTIFLIER METER LsAGE RECORDER INSERTION TATAL RECORDER REMOVAL TOTAL RECORDER TOTAL NET PULSE MULTIFLIER RECORDER TOTAL USAGE SUM CF RECORDED INTERVALS RECORDED USAGE RECORDED-METER USAGE &is WITHIN TOLERANTZE?YE YES PEAKING CHANNEL DATE TIME RANK.KW Kip A 94/26 01245 1 13744.00 13740.,00 a O4/2464 3230 2 13744.90 =613740.,00 A O4/26 123245 i}13744.00 132740.00 b=04/24 00215 1 127AOLOO =1LS740,00,B Q4/246 01:45 z IE7IALOG =TSF IAL OO B O4/24 OF2815 3 LE740.00 L37dIO LOO NO EXCEPTION: FIGURE1 SANGAMG BMIT FEAK REFORT 01/06/32 HEY=00200 10812345 ACOUNT #BMIT TEST #2 INSERTION 04/25 13846 CUSTOMER NAME EXAMPLE TEST 82 REMOVAL O4/26 15106 TIME CLASS 1 FROM BEGINNING TO END TOTAL KWH KQH PEAKING 41222 4t21 CHANNEL DATE TIME RANK KWH KOH KVAH STATUS a 04/28 01145 1 3436.06 3435.00 3988.97aA047260313023434.00 3435.00 3746.97 a 04726 OO11S 3 3435.00 3433.00 3966.37 8 04/26 COSIS i 34:25.00 3435.00 3964.39804/26 01145 2 3434.00 3433.00 3766.97 8 04/24 O3815 3 3435.00 3435.00 3966.39 KVA 04/26 01145 i 3434.00 3435.00 3966.97 KVA 04/26 03:30 2 3434.00 3435.60 3766.97 KVA 04/26 00815 3 3435.00 3435.00 3766.37 TIME CLASS 2 FROM BEGINNING TO ENO TOTAL,KWH KOH PEAKING 123636 1238603 CHANNEL OATE Time RANK KWH kQH KVAH STATUS a 047235 21015 1 3435.00 3434.60 3945.61 a 04/235 21845 2 3435.00 3434.00 3965.81 a 04725 25115 3 3435.00 3434,00 3965.81 5 O4/25 21015 1 3433.00 3434.00 3945.61 8 O4/ZS 21145 2 3435.00 3434.00 3765.81 8 04/25 22015 3 3434.00 3434.60 3945.24 Kva 04/7235 21815 4 3435.00 3434.00 3765.1 KVA O4723 21145 2 3435.00 3434.00 3965.81 KVA 94725 23015 3 3435.00 3434.00 3945.81 Time CLASS 3 FROM SEQINNING To END TOTAL KWH KOH FEAKING 149426 4169379 CHANNEL DATE TIME RANK KWH KOH KVAH STATUS A O4/28 13143 1 3436.00 3423.00 3966.97 - a 94725 14130 2 3435.00 3433.06 3965.24 a O4/25 15145 3 3435.00 3434.00 3765.81 8 04/28 13165 $3434.00 3435.C0)3966.978O4/25 14845 2 3434.00 3434.00 3945.24 8 O4/23 15945 3 3435.00 3434.00 3765.50 cowth)UMIT LISTING REFORT 01/25/57 rp,2 wed TO#l2245 ACCOUNT #BMIT TEST wt INSERTION 04725 13644 'TOMER NAME TECHNICAL BULLETIN REMOVAL 047726 15106 Ws twee KWH KWH KWH Wnt KWH KWH KWH TIME STATUS 0.00 0,00 0.00 0.90 0.00 Q.00 9.00 0,00 13100 0.00 0.00 0.00 0.00 0.00 0,00 3202.00 3201.00 44:00 9434.09 3423.00 3435.00 3433.00 3434.00 3434.00 3434.00 3433.00 135100 3a34.on 3433.00 3434.00 3433.00 3435.00 3434.00 3434.00 3433.00 16200 3434.00 3434.00 3435.00 3434.00 3435.00 3433.00 3434.00 3433.00 17:00 3434.60 3434.00 3434.00 3433.00 3434.00 3433.00 3434.00 3433.00 161006 3454.00 3433.00 3434.00 3433.00 2434.00 3433.00 3433.00 3432.00 19100 3433.00 3433.00 3434.00 3432.00 3433.00 3433.00 3434,00 3433.00 20800 3434.00 3433.00 3434.00 3433.00 3434.00 3433,00 3934.00 3433.00 21100 3455.00 3434.00 3434.00 3433.00 3425.00 3434.60 3433.00 3432.00 22300 3434.00 3434.00 3434.00 3432.00 3434.00 3433.00 3433.00 3433.00 23:00 3435.00 3434.00 3434.00 3433.00 3435.00 3434.00 3425.00 3433.00 24100 426 KWH KWH KWH KWH KWH Wid KWH KWH TIME STATUS 3435.00 3435.00 3435.00 3434.00 3435.00 3434.00 3435.00 3434.00 O1tvo 3435.00 3434.00 3435.00 3434.00 3426.00 3435.00 0.00 0.00 O2FOO 0.00 0.00 0.00 0.00 0.00 0.00 3435.00 3434.09 03300 3435.00 3435.00 3434.00 3435.00 3435.00 3434.00 3435.00 3433.00 04:00 3434.00 3434.90 3434.00 3433.00 3435.00 3434.00 3434.00 3433.00 OS100 3434.00 3433.00 3434.00 3433.00 3434.00 3433.00 3434.00 3434.00 06160 3433.00 3433.00 3424.00 3434.00 3435.00 3434.00 3435.00 3433.00 07:00 3434.00 3433.00 3434.60 3434.00 3435.00 3434.00 3434.00 3423.00 08100 3434.00 3433.00 3434.00 3434.00 9425.90 3433.00 3435.00 3434.00 09100 3434.00 3434.00 3435.00 3434.00 3455.00 3433.00 3434.00 3434.00 10100 2434.00 3433.00 3434.00 3433.00 3434.00 3433.90 3434.00 3433.00 1100 3434.06 3433.00 3434.00 3433.00 3435.00 3434.00 3434.00 3433.00 121800 3434.00 3433.00 3434.00 3434.00 3435.00 3433.00 3434.00 3433.00 13:00 3435.00 3434.00 3434.00 3434.06 3436.00 3435.00 3435.00 3434.00 14300 3434.00 3433.00 3435.00 3434.00 .3435.00 3434.00 3435.00 3434.00 15100 1332.00 1361.00 1Se1s FIGURE3 [AIT EXCEPTION REFORT 01/23/82 tn)1Os204S51 ACCOUNT ©BMIT ERROR TESTI INTERTION O8/712 15:57 ROMAME EXAMPLE TEST #3 REMOVAL O?P/1G 14:40 TIME STATUS DATE TIME STATUS DATE TIME STATUS UATE TIME STATUS DATE TIME STATUS GATE TIME STATUS so1m)oO 08/13 00:00 A 03/13 04:00 AB 03/13 08100 8 08/713 20100 O 08/14 00100 A 7.raton Aa 08/15 00100 a os/15 04t00 AB 03/715 98:00 AB 08/15 £2100 A 08715 20:09 8B °06000 AB 08/16 04100 a 08718 20100 8 08/17 00160 B 08/17 16100 a 06/17 20:00 AB 2 ansod RB 03/18 04:00 8 03/18 06100 8 03/21 06800 A 03/21 04100 AB 08/21 OG:00 8 7 423100 8 08727 16800 B 03723 146100 a 08/23 20800 A o9/Nt 20:00 O 09/02 12100 G sear re 14900 0 09/05 0:00 a 09/03 04100 a 09/6 00100 O 09706 24100 O C 09/06 20100 c eri 14100 0 07718 284840 a FIGURE4 - ra ottmehethiaJOrPROGRAM &FIXED DATA MODULES Software The main processing program is stored on a dedicated bubble module known as the program module and is loaded each time the BMIT is turned on.This provides flexibility in the software system since it allows Sangamo to easily make programming updates. The customer fixed data for up to 154 customers is stored on ancther dedicated bubble module, known as the fixed data module,which can be easily modified by the operatcr through the printer keyboard.The customer instailations are identified by a unique five-character : identification number selected by the operator (this can be tiie same as the recorder I.D. number written on the field data module by the MBR-90).Fixed data for each installation is accessed through this number.The rate schedules used in the peak report (maximum of three)are also stored in the fixed data module. Each rate schedule has the capacity for a weekly pattern,three daily patterns per week, three time classes and a "zero”or null class, and 25 holidays. The demand interval length can be 15,30,or 60 minutes,according to customer preference. Reports The BMIT-90 generates the following translation reports,examples of which are found in the accompanying figures: 1)The summary report ("SUM”)in Figure 1 prints a summary report almost identical to that generated by the larger Sangamo ST-21 translation system.It includes: -dates,times,meter readings,and recorder readings both on and off -whether or not the recorded intervals, running totals,and meter readings agree -three peaks for channels A and Bin demand units with the coincident data for the other channel -the number of intervals with exceptions. 2)The peak report ("PEAK”)in Figure 2 prints the total consumption and the three highest peaks in time classes 1,2,and 3 for each channel and,if selected,for KVA or the total of the two input channels.The operator selects the start and stop times for each peaking report.The peaking parameter displayed can be in terms of pulse counts, energy,or demand;if KVA is selected,it can be in KVA or KVA demand.The coincident data in the other channel for each peak is also printed. 3)The listing report ("LIST”)in Figure 3 lists all intervals Detween any operator selectable start and stop times.The parameter displayed is operator selectable as in the peak report. 4)Tne exception report ("EXC'')in Figure 4 prints the date,time,and status code of each four-hour period (or eight-hour period with 1 channel recording)that had an exception. Both listing and peak reports may be performed for any selected time interval within the recordir period,or over the entire recording period. Translation times for summary,peak,and exception reports are less than one minute.KVA peak reports are generated in less than six minutes.Listing reports are printed at the printer rate. 'Specifications BMIT-90Dereon20Ibs. Physical Dimensions WW"K 10%"K 14%" Power Requirements 115 or 230 VAC +15%50/60 Hz High Potential Withstand 2500 VAC .Lat Ambient Operating Temperature 0°to 50°C (32°to 122°F) Ambient Operating Humidity 0 to 95%non-condensing Demand Interval 15,30,or 60 minute selectable Baud Rate 300 to 9600 switch selectable Interface Requirements RS232 modem Rate Schedules 3 Time Classes 3 plus a "ZERO”class Fixed Data Capacity 154 customers installations per fixed data module plus 3 rate schedules. °'pes of Reports Summary,peak,exception,and listing Q ,SANGAMO WESTON Sangamo Energy Management Division P.O.Box 48400 Record Copy File #QF PRA 2-4 ALASKA INTERTIE OPERATING COMMITTEE WEDNESDAY,JULY 10,1985(At University of Alaska,Fairbanks) Attendance: Ken Ritchey Matanuska Electric Association John C.Marshall Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Larry Colp Fairbanks Municipal Utilities System Sam Mathews Homer Electric Association Mike Massin Anchorage Municipal Light and Power Stan Sieczkowski Alaska Power Administration John Aspnes University of Alaska-Fairbanks George Mulligan University of Alaska-Fairbanks Ed Morris Alaska Power Authority Afzal Khan Alaska Power Authority Howard Thacke Alaska Power Authority Harry Beck Alaska Power Authority Dan Rice Gilbert/Commonwealth The meeting was called to order by Chairman Mike Massin at 9:25 a.m.in Room 118,Duckering Building,University of Alaska,Fairbanks. Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unani- mously. The agenda was adopted as submitted. Under Committee Correspondence and Reports,the Committee received no correspondence since the last meeting. Bob Orr gave a report on the meeting held by SCADA/METER- ING/COMMUNICATIONS Subcommittee.The meeting was held on July 9, 1985 at 9:00 a.m.at the Golden Valley Electric Association Train- ing Room.(Bob Orr also furnished the Operating Committee with a set of minutes which are attached). Marvin Riddle also provided the Operating Committee a brief report on the Dispatch Scheduling Subcommittee meeting.This meeting washeldonJuly9,1985 at the Golden Valley Electric Association Training Room. John Marshall discussed the under frequency load shedding plan.The under frequency load shedding plan is same as submitted in the 9894/410 AIOC |utes July 10,1985 Page 2 previous Operating Committee meeting.Bob Orr submitted the underfrequencyloadretentionplanforNorthCentralAlaska. Afzal Khan from the Alaska Power Authority was then asked to provide the Operating Committee with a status report on the Alaska Intertie.He reported that the Goldhil]transformer passed the factory tests.The transformer was scheduled to be shipped on July 5,1985.The Westinghouse Electric will submit a detailed schedule.The installation and testing will take place in later part of August,1985.As for SVS problem at Healy and Goldhill substations,Gilbert/Commonwealth came up with a recommendation to the SVS problem.The recommendation is passed on to General Electric.The Alaska Power Authority is waiting for General Electric to reply.Afzal Khan submitted a report on harmonicmeasurementsatHealysubstationbyGilbert/Commonwealth.Afzal Khan introduced Harry Beck,who joined the Alaska Power Authority. There were no visitor comments;however,Mr.John Aspnes from the University of Alaska,Fairbanks did sit in as a visitor.John 'Aspens briefly discussed the Dispatcher Training sessions.He indicated that the Interim Report is modified to reflect the comments made by the committee members.He was advised to ask Utilities to provide relay data.He informed the committee members that the cutoff date for the project is mid September. The Operating Committee had no old business to conduct at the meeting. The Operating Committee recessed into a break from 10:35 a.m.to 10:55 a.m. Turning to SCADA/METERING/COMMUNICATION SUBCOMMITTEE,Bob Orr indicated that there is not much to add other than that which had already been indicated in the minutes. Marvin Riddle briefly discussed the Alaska Intertie Transaction form,which he submitted. The Operating Committee adjourned at 12:15 p.m.for lunch and reconvened at 1:25 p.m. Ed Morris briefly discussed the Ahtna,Inc.claim with the commit- tee members.Ed Morris also discussed the Alaska Intertie Agree- ment. Afzal Khan then discussed the remaining Intertie startup/testing plan.John Marshall brought to the committee's attention the modifications to the Teeland substation.Bob Orr requested a copy of Test and Acceptance plan for all static var systems on the Alaska Intertie. 9894/410 AIOC 'utes July 10,1985 Page 3 The Committee Budget was briefly discussed and decided to takeactionunderFormalOperatingCommitteeaction/recommendations. There was a question as to how Operating Committee can bill to Alaska Power Authority. It was noted that there were no comments submitted to Gilbert/Commonwealth on Transmission Loss Study and Operating Procedures.Dan Rice briefly discussed the Operating Procedure and Transmission Loss Study. John Aspnes distributed a copy of the report titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected System" to the Committee members.John Aspnes offered to give a tour of University of Alaska,Fairbanks computer center.The Committee members decided to take a look at the computer center after the meeting. John Marshall motioned for acceptance of Operating Committee budget of $183,399.00 and that the budget recommended be forwarded to theAlaskaPowerAuthority(Afzal Khan)under a cover letter from the Operating Committee Chairman.Bob Orr seconded the motion.The Operating Committee members unanimously approved the motion. Sam Mathews motioned that the Intertie Operating Procedures and Transmission Loss Study be dated whenever there is a revision. Mike Massin seconded the motion.The Committee members unanimously adopted the motion. Bob Orr then motioned that the Anchorage-Fairbanks Intertie be recognized as an Alaska Intertie.Mike Massin seconded the motion. The Committee members adopted the motion. Chairman Mike Massin then directed the SCADA/METERING/COMMUNICATIONS AND RESERVES/LOADSHED SUBCOMMITTEES TO MEET ON TUESDAY,AUGUST 13,1985 AT 9:00 A.M.IN THE ENGINEERINGCONFERENCEROOMOFCHUGACHELECTRICASSOCIATION. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM- MITTEE TO MEET ON TUESDAY,AUGUST 13,1985 AT 1:00 P.M.AT THE CHUGACH ELECTRIC ASSOCIATION ENGINEERING CONFERENCE ROOM. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ALASKA INTERTIE OPERAT- ING COMMITTEE WILL BE ON WEDNESDAY,AUGUST 14,1985 at 9:00 A.M.IN 9894/410 AI0C t utes July lu,1985 Page 4 THE MAIN CONFERENCE ROOM OF MUNICIPAL LIGHT AND POWER AT 1200 EAST FIRST AVENUE,ANCHORAGE,ALASKA. Larry Colp motioned for the meeting to adjourn.John Marshall seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 3:00 p.m. Respectively submitted,lifeHMBhocw Afzal H.Khan -Secretary Alaska Intertie Operating Committee Attachments: 1.August meeting Agenda. 2.Minutes from July 9,1985 SCADA/METERING/COMMUNICATIONS Subcommittee meeting. 3.Underfrequency Load Retention Plan for North Central Alaska. 4.Alaska Intertie Transaction Form. 5.Alaska Intertie Operating Committee Fiscal year 1987 Budget.6. G/C letter to Alaska Power Authority (Dave Eberle -HarmonicsMeasurementsatHealyPowerPlant). 7.Letter from John Aspnes to Afzal Khan regarding Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System. AHK/cdc 9894/410 ALASKA INTERTIE OPERATING COMMITTEE©-AGENDA- WEDNESDAY,AUGUST 14,1985 BEGIN AT 9:00 A.M, I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports "RK,-SCADA/Metering/Communications SubcommitteeBS. Dispatch/Scheduling Subcommittee -JiAn Cow fy orng miredC.=Reserves/Loadshed CoselefenAoncD.Intertie Status Update (A.P.A.)G)[nsurance ©)Sur of ref shhesIV.Visitor comments related to items "on agenda”( V.°-Old Business VI.New Business VA.Recess and work session +B.SCADA/Metering/CommunicationsvsDispatch/SchedulingD.Reserves/Loadshed retintron E.Operating Procedures-.--_triversity of Alaska,Fairbanks DynamicStabilityStudyjoe2G.Others VII.Formal Operating Committee action/recommendation VIII .Subcommittee assignments IX.Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light and Power Main Conference Room 1200 East First Avenue Anchorage,Alaska (907)279-7671 9894/410 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE -AGENDA- WEDNESDAY,JULY 10,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A. SCADA/Metering/Communications Subcommittee B.Dispatch/Scheduling Subcommittee C.Load Retention Plan D.Intertie Status Update (A.P.A.) IV.Visitor comments related to items on agenda V.Old Business VI.New Business .Recess and work session SCADA/Metering/Communications C.Dispatch/Scheduling A B C D.Interim Agreement E.Intertie Startup/Testing F.Committee Budget G. Review/comments -Loss Study,Operating Procedures H.Other VII.Formal Operating Committee action/recommendation VII.Subcommittee assignments IX Adjournment Adjourn by 3:30 p.m. Meeting location:University of Alaska -Fairbanks Room 118,Duckering Building Department of Electrical EngineeringFairbanks,Alaska 99701 (907)474-7137 9313/383 VIL MEETING MINUTES SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE DATE:July 9,1985 9:00 a.m. PLACE:GVEA SCADA Training Room PERSONS IN ATTENDANCE: Robert Orr GVEA Alan Martin FMUS Vance Cordell CEA Dan Rogers CEA John Cooley AML&P Afzal H.Khan APA Dan Rice G/C Ray L.Duncan CEA Ken Ritchey MEA Marvin Riddle GVEA Henri Dale GVEA The purpose of the meeting as directed by the full committee was to provide an update on the data link efforts. Following is present status of Data Link efforts by utility: AML&P Hardware is to arrive at AML&P on 7-19-85 and they will be ready for testing on 8-13-85. GVEA Will be ready for testing on 8-15-85 per test plan.GVEA will resolve factory support issue for testing at Fairbanks. GVEA will make the necessary arrangements with L&G to insure adequate factory support is on hand at Fairbanks to insure the testing goes smoothly. CEA Need to meet with APA to finalize their proposal.Have sent proposal to APA.The proposal is for CEA to be a routing node using DecNet initially on approximately 6-1-86,then later develop an emulation of DecNet. Other items to be confirmed or finalized are: 1)Final acceptance of joint test procedure.The June 28 draft of this document is in the final phases of review. 2)Conformation with Mike Ridge of the State Department of Communications must be made on them providing the four 9609 baud modems and having them installed and operational by 8-1-85. Afzal H.Khan of APA will follow up on this item. The meeting proceeded to a discussion on where each utility was presently at with their SCADA systems.Following is the current status by utility. 7-9-85 Page 2 CEA They are in their new facility and operating from their new SCADA system with approximately 16 RTU's installed. GVEA Operating on 8598 SCADA system in new facility with all 32 substation and powerplant RTU's.Five micro RTU's at communications sites are yet to be installed.The following SCADA advanced application packages are operational:AGC, economic dispatch,unit commitment,fast load shed,fast restoration,cold load pickup calculations,sequence of events,archiving and meter error analysis.The following packages are in the modification or implementation process: transaction evaluation,on-line load flow,REA outage reports,fast load shed,disturbance analysis and energy accounting.The following packages need to be implemented: real-time training simulator,FMUS remote consoles,FMUS RTU's and data link. FMUS South side RTU is installed but not operational.By end of July expect to install remote consoles and tie south side RTU to GVEA master station.Rest of plant/substation modifications and installation of remaining RTU's are not to be completed until February or March,1986. AML&P,All distribution substations and two plant RTU's are installed and operational.This includes Douglas and Teeland RTU's.Eclutna RTU installation is in progress. The meeting discussion then turned to determining what projects the subcommittee should be working on in the future.Following are the recommendations for assignment by the fall committee: 1)Look at standardization for all tie metering points as well as other critical intermediate points.Standards need to be developed for MW and MVar readings with no multipliers.Letters need to be sent to all utilities recommending they implement these standards. 2)Develop a plan and procedures for calibration,sealing and intervals for routine checks of all tie revenue metering.Use intertie agreement as a starting point.Develop a plan and procedure for determining that information received at each control center is adequate and in proper formats for Dispatcher control and accounting. The meeting adjourned at 11:48 a.m. LENGaSubcommitteeChairman STEP UTILITY/ CIRCUIT/ SUBSTATION(S) GVEA/HAS R1,R3 HOS R1,R3,R4 System GVEA/ZNS R2,R3,R4 System GVEA/BKS R2,R4 SFS R1,R2,R3 FHUS/Lathrop Westgate System GVEA/HLS R1,R2 HAS R2,R3 UAS R1,R2,R3 System GVEA/CPS RI,R4 STS R2,R3,R4 CWS RI,R3 System 59-2 59.1 59.0 58.9 UNDERFREQUENCY LOAD RETENTION PLAN FOR NORTH CENTRAL ALASKA WINTER 1985-1986 PEAK TIME DELAY (CYCLES) 10 10 10 10 10 Moura TE€ LOAD LOAD PERCENT SHED REMAIN SHED (HW)(MW)(%) 9.4 8.7 9.4 99.0 8.7 6.5 6.1 6.5 92.4 6.1 7.8 |7.2 ve 4d 3.8 11.9 80.5 11.0 11.3 10.4 1.3 69.2 10.4 9.4 8.7 9.4 59.8 8.7 7-9-85 CUMULATIVE CUMULATIVE PERCENT LOAD SHED (%)(HW) 8.7 9.4 14.8 16.0 25.7 27.9 36.2 39.2 44.8 48.6 Page 2 UNDERFREQUENCY LOAD RETENTION PLAN FOR NORTH CENTRAL ALASKA WINTER 1985-1986 PEAK . 7-9-85 UTILITY/TIME LOAD LOAD PERCENT CUMULATIVE CUMULATIVE CIRCUIT/FREQ.DELAY SHED REMAIN SHED PERCENT LOAD SHED STEP SUBSTATION(S)(Hz)(CYCLES)(HW)(Mw)(%)(%)(Mw)- 6 GVEA/BRS R1,R2,R3,R4 58.8 10 10.2 9.4 PGS R2,R4 FMUS/First Ave.30.6 9.8 Fourth Ave. Garden Island System 20.8 39.0 19.2 64.0 69.4 7 GVEA/HPS R1,R2,R3 58.7 10 12.9 11.9 JRS R2,R3 JCS R1,R2 a FMUS/Egan Ave.3.5 3.2 System 16.4 22.6 15.1 79.2 85.8 8 FHUS/Sewer Teatment 58.6 10 3.3 3.0 Plant --_-___ System 3.3 19.3 3.0 82.2 89.1 Loads GVEA/FXS RI Not Shed (12.0)(11.1) Not GHS RI Shed IAS R1 1985-1986 Winter Peak JCS R3 JRS RI GVEA 79.4 MW NNS RI,R2 FMUS 29.0 MW ZNS RI -st FHUS/Barnett (7.3)(6.7)Total 108.4 Hw Cowles eo Ae (19.3)(17.8) GVEA GENERATION &TRANSMISSION INTERTIE UNDERFREQUENCY TRIP SETTINGS 7-9-85 TYPE LOCATION RELAY DELAY RELAY TYPE SETTING Intertie ELP 59.4 19 HZ UNK Intertie UVP 59.3 6 HZ CFF Intertie ANC-FAI 59.9 20 HZ KF Intertie MUS 58.3 20 HZ KF Intertie FGP 58.8 1.5 HZ CF-1 Intertie FWP 57.0 UNK CFF Genetfation NPP-GT#1 57.8 UNK Speedtronic 95%Speed Generation NPP-GT#2 57.¢UNK Speedtronic 95%Speed Generation ZNP GT#1 58.2 30 HZ CFF Generation _ZNP GT#2 58.2 38 HZ CFF Generation ZNP DIESELS None ---- Generation HLP ST#1 59.75 UNK UNK FREQUENCY CONTROLLER *MUS intertie underfrequency trip is conditional upon 58.3 HZ and4.9 MW or more of power flowing in MUS direction. GVEA UNDERF.._JJENCY "SHED"TRIP POINTS cOR DISTRIBUTION FEEDERS 7-9-85 U/F TRIP SUBSTATION +40°R §°F 49°F POINT (HZ)RECLOSER KW %LOAD |KW %LOAD |Kw $%LOAD (59.5 (1)HLS/RL 59.3 HAS/R1L,R3 3368 9 4848 12 5635 12 MOS/R1,R3,R4 1809 2722 3809 59.2 ZNS/R2 99 8 70 8 115 8 ZNS/R3,R4 4287 17*5254 20*6460 20* 59.1 BKS/R2,R4 1224 13 16690 19 2088 10 SFS/R1,R2,R3 5681 30*5916 30*5669 30* 59.9 HLS/R1,R2 3400 18 3476 15 3973 14 IAS/R2,R3 3306 48*2825 45*3718 44* UAS/R1,R2,R3 3006 3658 3565 58.9 CPS/R1,R4 1966 9 2856 11 3969 12 STS/R2,R3,R4 2500 57*3796 56*4763 56* CWS/R1,R3 530 606 706 58.8 BRS/R1,R2-R3,|2880 ll 3691 12 4657 13 R4 PGS/R2,R4 "3260 |68*4246 68*5571 69* 58.7 HPS/R1,R2,R3 4450 16 5261 16 6296 16 JRS/R2,R3 14096 84*1646 84*1848 85* JCS/R1,R2 3006 3649 4819 FXS/RL1 1556 1629 2004 LOADS NoT GHS/R1 436 16 515 16 733 15 SHED IAS/R1 1290 1452 1998 JCS/R3 3006 3046 3919 JRS/R1 1459 (1408 1579 NNS/R1,R2 130¢1408 159¢ ZNS/R1 18a 250 363 TOTAL (2)54712.63939 79367 NOTE: (2)Totals do not include: For -49°F the approximate loads are 2500 KW for U of A, 519@ KW for Eielson,FMUS and FWW. *Indicates cumulative percent of load shed to frequency indicated. *Indicates 28 cycle delay for JRS and JCS (all others are 18 cycle delay). U of A,Eielson,(1)When 3.4 MW in Usibelli's direction (instantaneous trip). FMUS or FWW loads. FMUS UNDERFREQUENCY "SHED"TRIP POINTS 7-9-85 Shed Point Feeder Name @-49°FR Total Shed Load MW %Cumulative 58.3 w/28 cy delay FMUS-GVEA tie (Zehnder) 59.1 HZ Lathrop 1.6 5.5 59.1 HZ Westgate 2.5 8.5 14.0%_| 58.8 HZ First Ave 4.0 14.6 58.8 HZ Fourth Ave 1.8 6.@ 58.8 HZ Garden Island 4.8 16.5 508.5% 58.7 HZ * . Eagan Ave 3.5 12.6 58.6 HZ *Sewer Treat Plt 3.3 11.4 73.5% Not Shed Barnett (WTP)1.5 5.0 Cowles 6.0 20.5 29.0 MW Net Total *These southside substation feeders are not U.F.shed as no remote control in service,shed level,will be implemented when remotecontrolisavil(approximately 8-15-85). All relays are 10 cycle delay except as otherwise indicated. Loud 1070 t |,MAATES -ALASKA,> DCO Dida mNG INTERTIE TRANSACTION DATE //TINE t *TRANSACTION DATE // REQUESTED BY _START TIME /__/3s RAMP RATE /STOP TINE //.t SUPPLIER,/:RECELVER CLASSOF ENERGY ' we .*€;a ' :ol0d 020d 030d 040d 0500 0600 070q o60q 050g 100g 1log 1 20g 130m 140g 150 1600 170q 1800 1900 200g 2100 2200 2300 2400 DAILY TOTAL ZENDER (PMUS/GVEA}.a "|-t aan i LOSS ZONE Gl . -.!; :\ HEALY EL.on ee eee "Pood se iy Zid 1/2 LOSS ZONE TI.t .a :fo.eqn a ! nrppornt <p -To Lin IS,are oo |e reaps =nf , al ;.Pe.'t1/2 LOSS ZONE TI 'a].poo d-a].en f f DOUGLAS : a4.;:7 b.ae ' . o>':t-'':;a .Re ,LOSS 20NE Cl -ff opie !: i eee Re "< PLANT 2/230 yd (CEA/AMLP)|i ':ayo iY woe -PF ;LOSS ZONE (C1+C2);Oe : SOLDOTNA (CEA/HEA)bo%... . Intertie Operation and charges are based on Midpoint Schedule SeoeeetK 0200 Gamal 4 FHUS bene,tole from WER beneonTSlendGI tadgrsew ,APA Bie We Ped Gee IOC SHUM Rad Tre eduadellfnTe tC .HW odom Crema BUCH Lyn ZoMud from MUP bewdon 15 %a lens C4,te Sone ROW coasts gaat fo.20,02HIN RaShreTar Ren ttan Seve tantrafetbwetseateatesadvabeasmonThepoetieohagyoBoag6/65 Alaska In'tertie Operating Committee RECEIVED JUL261985July25,1985yer ALASKA POWER AUTHORITY Alaska Power Authority 334 West Sth Avenue Anchorage,AK 99501 Attention:A.H.Kahn Reference:Alaska Intertie Operating Committee Fiscal Year 1987 Budget Dear Mr.Kahn: At the July 10,1985 meeting of the Alaska Intertie (Anchorage/ Fairbanks)Operating Committee,the Committee took a formal action on a requested Operating Committee Budget for the fiscal year 1987.I have attached a copy of the proposed budget. Please note that the amount of $183,399 is unchanged from our request of March 23,1984 which was then sent to Mr.Mike Yerkes. We respectfully request that this budget requirement be placed in the Alaska Power Authority's budget submital to the 1986 Legisla- tive Appropriation Request.We further request that you keep the Operating Committee advised,in writing,as to the status of thisrequestorifany.problems are encountered. Sincerely, Mick Mas Mike Massin Chairman Alaska Intertie Operating Committee MEM/csn cc:R.Orr (GVEA) J.Marshall (CEA) July 10,1985 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) Amount $20,000 30,000 5,000. 10,000 See 1)above 5,000 -0- 101,399 12,000 See all above $183,399 ALASKA INTERTIE OPERATING COMMITTEE BUDGET FISCAL YEAR 1987 Subcommittee Dispatch/Training SCADA/Comm/Meter Handbook/Procedures Machine Rating Dispatch Scheduling Reserves /Loadshed Relay Protection Reliability/Criteria Full Committee Budget TOTAL BUDGET REQUEST Purpose 50%Training Materials 50%Operating Manual Studies (such as) Composite Power Flow Data Link Loading Drafting and Supplies for Manual Drafting Generation Standards Manual Generation Manual Review &Assembly Outside Review and Coordination of Load- shed Post Fault Analysis and Data Base Upkeep Secretarial Services for Minutes and Typing/ Copying 1104 TES if Gilbert /Commonwealth engineers ang consultants GILBERT /COMMONWEALTH INC.OF MICHIGAN,209 E.Washington Avenue,Jackson,MI 49201/Tel.517 788-3000 May 23,1985 REAPAI-20597 "SCEry Ep Mr.David R.Eberle Alaska Power Authority 334 West 5th Avenue Anchorage,AK 99501 Dear Mr.Eberle: SUBJECT:ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE PROJECT MEMORANDUM REPORT HARMONICS MEASUREMENTS AT HEALY POWER PLANT Enclosed is our "Memorandum Report -Harmonic Measurements at HealyPowerPlant"for your review and comment.This is the only distribution|which we will make of the report until we receive instructions from you. A similar report for the Teeland substation measurements is in preparation and we expect to mail it within one week. Sincerely, BE?TleG.MiTier,P.E. LGM/1jr Enclosure 525 Lancaster Avenue,Reading,PA/Morgantown Road,Green Hills,Reading,PA 215 775-2600 209 East Washington Avenue,Jackson,Mi 517 788-3000 MEMORANDUM REPORT HARMONIC MEASUREMENTS AT HEALY POWER PLANT FOR THE , ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE PROJECT -Prepared by J.T.Hancock,P.E. Gilbert/Commonwealth Inc.of Michigan May 23,1985 MEMORANDUM REPORT HARMONIC MEASUREMENTS AT HEALY POWER PLANT Prepared by Gilbert/Commonwealth Inc. SCOPE Harmonic current measurements were made in current transformer secondary circuits for the Healy generator,24.9 kV feeders Rl (Usibelli Coal Mine)and R2 (West River)and the Gold Hill 138 kV transmission line. 'Harmonic voltages were measured in 120 volt potential transformer circuits for the generator bus,24.9 kV bus and 138 kV bus.Measurements were made on April 16,17 and 20,1985 under various operating conditions of harmonic producing equipment at the Usibelli Coal Mine (UCM). CONCLUSIONS 1.The measured Healy generator harmonic currents are less than 1 percent of the fundamental current.The 5th harmonic currents are 0.6 percent or less and 7th harmonic currents are 0.4 percent or less.Based on these observations it can be concluded that for operating conditions similar to those measured:a)the Healy generator has not been exposed to significant harmonic currents.and b)that generator harmonic levels vary insignificantly as UCM operating modes change. 2.The relatively consistent harmonic current levels on the West River feeder R2 suggest that harmonic sources exist on the feeder. 3.When the UCM capacitors are disconnected,harmonic currents for the llth and 13th harmonics (7.3 percent and 4.9 percent respectively) are injected into the 24.9 kV power system. 4.Harmonic voltage distortion factors for the 24.9 kV and generator buses satisfy recommended levels.The harmonic voltage distortion factor for the Gold Hill 138 kV line slightly exceeds recommended levels but this does not necessarily indicate a problem. JTHancock 5/23/85 Paqe 1 of 9 RESULTS AND DISCUSSIONS The results of the measurements are summarized in Exhibits 1 and 2 and are expressed as a percent of the 60 Hz fundamental frequency components. For current measurements,all results are referenced to the 60 Hz currents measured during "Normal”conditions.Voltage measurements are referenced to the 60 Hz voltages measured for that load case.The several UCH operating conditions existing during the measurements are described in Exhibit 3. 1. A review of the harmonic currents in Exhibit 1 shows: harmonic currents produced by the UCM peakshaver have a major effect only on the 24.9 kV feeder R1 to UCM. harmonic currents at the generator are small (1 percent or less) and change relatively little for various UCM operating modes.The 5th harmonic current varfes between 0.3 percent and 0.6 percent of formal 60 Hz current and the 7th harmonic stays relatively constant at 0.3 percent to 0.4 percent. Significant increases in 60 Hz currents were noted at all measurement locations when the UCM capacitors were disconnected and normal dragline operations were occurring. With the capacitors disconnected,several notable differences in harmonic levels on the UCM feeder R1 existed: -harmonic 7,0.5 percent compared to 4.8 percent for normal. harmonic 11,7.3 percent compared to 4.1 percent for normal. -harmonic 13,4.9 percent compared to 0.5 percent for normal. Disconnecting UCM capacitors had no significant effect on harmonic levels,above the 3rd harmonic,in the West River feeder R2 and Gold Hill 138 kV line.Slight increases in harmonics 11 and 13 were observed with the capacitors off. JTHancock 05/23/85 new nm fn An overall measure of harmonic voltage effects on power system voltage is the voltage distortion factor expressed as a percent of fundamental. The voltage distortion factor is defined [1]as 1/2Sumofthesquaresofallharmonicvoltageamplitudes x 1003 square of fundamental voltage amplitude Recommended levels for voltage distortion [1]for general power systems are: 2.4 kV -69 kV 52 115 kY¥and above 1.52% Voltage distortion levels on the generator bus and 24.9 kV bus satisfy the recommended limit.Voltage distortion for the 138 kV bus is 2 percent and slightly exceeds the recommended level.This does not necessarily indicate that a problem exists.. Individual harmonic voltage levels for "Normal"operating conditions are generally larger than for other operating modes.Two exceptions occur for the capacitors off case for the llth and 13th harmonic voltages on the 24.9 kV bus.These higher levels are a result of 11th and.13th harmonic currents injected into the 24.9 kV system from the UCM peakshaver when the capacitors are disconnected. SOURCES OF HARMONIC CURRENTS AND VOLTAGES Any nonlinear circuit element driven by a sinusoidal voltage source will generate harmonic currents.In power systems the most common nonlinear circuit elements are magnetic devices,i.e.,generators,transformers and reactors.However,such devices are designed to operate below magnetic saturation thereby minimizing the nonlinearities and harmonics produced when energized at rated voltages. JTHancock 05/23/85 Page 3 of 9 Solid state switching devices (SCRs and thyristors)used in rectifier/inverter applications are another source of harmonics.At the Usibelli Coal Mine,the peakshaver,is an ac-de electromechanical system which stores energy in mechanical form during non-peak load times and returns energy to the power system when peak power requirements by the dragline exceed a preset level.This arrangement reduces the peak power the utility is required to supply.The peakshaver rectifier/inverter produces and injects small harmonic currents into the power system. The UCM peakshaver rectifier/inverter is a 12-pulse system.The llth and 13th harmonics are the lowest frequency harmonics generated by an ideal 12-pulse system.In practical systems low levels of 5th and 7th harmonics may also be present. OPERATING CONDITIONS DURING MEASUREMENTS Exhibit 3 summarizes the operating conditions during the measurements. Measurements made on April 16,1985 were for normal UCM operations. April 17 was a scheduled maintenance day.Reduced dragline loads occurrea as the dragline buckets were positioned for repair.Later,all dragline operation was stopped,and both the peakshaver and capacitors at UCM were de-energized.The 24.9 kV-6.9 kV transformer,however,remained energized.On April 20 measurements were made for normal dragline operation but with UCM capacitors de-energized.At about 1230 hours, April 20,UCM completely de-energized the dragline,capacitors,peakshaver and the 24.9 kV-6.9 kV transformer'for a short time. MEASUREMENT SYSTEM The measurement system consisted of a Hewlett Packard (HP)spectrum analyzer (HP3580A)and X-Y Recorder (HP70458).For current measurements a 0.1 ohm resistor was inserted in series with the current transformer (CT)secondary circuit using a Westinghouse test switch.A transformer was used to isolate the measurement equipment from the CT circuit. JTHancock 05/23/85 Page 4 of 9 Exhibit 4a shows the circuit.For voltage measurements a 10:1 resistive voltage divider was used to reduce the potential transformer (PT)secondary voltage (about 120 volts)to less than maximum instrument input voltage. See Exhibit 4b. | The HP 3580A spectrum analyzer is equipted with an internal calibrator which allows calibration of the instrument.Calibration was checked periodically. "External components (isolation transformer circuit and voltage divider) were calibrated using the internal signal source (tracking oscillator) in the HP3580A which provides a variable frequency voltage source. The HP7045B X-Y recorder was adjusted to plot graphs equivalent to the display on the spectrum analyzer.The frequency scan time on the HP3580A was adjusted so that the plotter properly reproduced the spectrum display. For most measurements a scan time of 10 seconds per division was used giving an overall scan time of 100 seconds.A few measurements used a scan time of 20 seconds per division. Most measurements were made over the frequency range 0-5 kHz (83rd harmonic)A few measurements were made over the range 0-2 kHz (33rd harmonic).All measurements were made using a spectrum analyzer bandwidth of 10 Hz.The 10 Hz bandwidth gave adequate frequency discrimination to easily resolve the various harmonics present. REFERENCE 1.IEEE Standard 519-1981,Guide for Harmonic Control and Reactive Compensation of Static Power Converters. JTHancock 05/23/85 Page 5 of 9 EXHIBIT 1 -HARMONIC CURRENTS AT HEALY 60 Hz Harmonic Generator Fund.3 5 7 9 11 13 (2)(2)(2)(2)(2)(2)(2) Normal 100.0 1.0 0.4 0.3 0.1 0.1 - Reduced 94.4 0.7 0.3 0.3 0.1 0.1 - OCP OFF 94.4 0.7 0.3 0.3 0.1 0.1 - Cap.OFF 112.2 0.9 0.6 0.4 0.1 0.1 0.1 UCM 24.9 kV Feeder Rl Normal 100 2.8 2.5 4.8 1.2 4.1 0.5 Reduced 29.9 0.9 0.6 0.3 0.1 0.2 0.1 DCP OFF 28.2 0.6 0.5 0.3 0.2 0.1 0.1 Cap.OFF 112.2 2.0 2.4 0.5 0.3 7.3 4.9 6.9 kV Sub OFF 8.9 0.8 0.6 0.4 0.2 0.2 - West River 24.9 kV Feeder R2 Normal 100 4.6 5.0 3.4 1.2 1.2 0.3 Reduced 112.2 4.9 4.7 2.9 0.9 1.4 0.2 Cap.OFF 125.9 5.5 5.0 3.4 1.3 2.0 0.5 Gold Hi11 138 kV Line Normal 100 1.3 0.5 0.4 0.1 0.5 0.3 DCP OFF .100 1.2 0.4 0.3 0.1 0.4 0.2 Cap.OFF 112.2 1.6 0.4 0.4 0.1 1.2 0.5 Note:Measurement conditions are described in Exhibit 3. JTHancock 05/23/85 Page 6 of 9 Generator Bus Normal Reduced DCP OFF Cap.OFF 24.9 kV Bus Normal Reduced DCP OFF Cap.OFF° 6.9 kV Sub.OFF 138 kV Bus Normal Reduced DCP OFF Cap.OFF Note:Measurement conditions are described in Exhibit 3. JTHancock 05/23/85 Page 7 of 9 EXHIBIT 2 HARMONIC VOLTAGES AT HEALY 100 -100 100 100 100 100 100 100 100 Harmonic 3a 3 7 3 1 13 (2)(2)(2)(2)(2)(3) 3.8 1.6 0.6 0.2 0.5 0.1 0.2 0.9 0.3 -0.1 - 0.2 1.1 0.2 -0.1 - 0.1 1.0 0.2 -0.1 - 2.7 2.5 1.0 0.3 0.5 0.1 0.5 1.1 1.1 0.1 0.3 0.1 0.5 1.1 0.5 0.1 0.3 0.1 0.4 1.1 0.4 0.1 1.1 0.3 0.4 1.0 0.5 0.1 0.3 - 1.2 1.5 0.4 0.1 0.3 0.1 0.3 1.3 0.5 -0.2 0.1 0.4 1.6 0.5 -0.1 0.1 0.3 1.4 0.4 -0.3 0.3 Voltage Distortion (2) 4.2 1.0 1.1 1.0 4.0 1.6 1.3 1.8 1.2 2.0 1.5 1.7 1.6 EXHIBIT 3 -HARMONIC TEST CONDITIONS UCM 24.9kY Equipment Dragline Peakshaver UCM Capacitors 6.9kV XFMR Condition Normal Normal Digging In Service In Service In Service Reduced Hot Digging ..But Moving ,Bucket In Service In Service In Service OCP Off Not in Not in Not in Service Service Service In Service Cap.Off Normal Not in Digging In Service Service In Service 6.9 kV Sub Off Not in Not in Not in Not in Service Service Service Service JTHancock 05/23/85 Page 8 of 9 EXHIBIT 4 -MEASUREMENT CIRCUITS .101 1800.n WW-3-0 TO CT SPECTRUM O.1n 680 ANALYZERCIRCUIT .adi 0/ ISOLATION TRANSFORMER A)HARMONIC CURRENT MEASUREMENT 44.7Kn. =-o-_Wh Oo' -TO PT 4 .SPECTRUMCIRCUIT"7Kn ANALYZER INPUT 20.5 dB VOLTAGE DIVIDER B)HARMONIC VOLTAGE MEASUREMENT JTHancock 05/23/85 Page 9 of 9 UNIVERSITYOF ALASKA,FAIRBANKSFairbanks,AlaskkX%%X 99775 10 July 1985 Afzal H.Khan,Director Systems Operations and Engineering Alaska Power Authority 334 W.5th Ave.,2nd Floor Anchorage,AK 99501 Dear Mr.Khan: Enclosed is an interim report for the project titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System." A draft report by the same title was sent to you on May 30,1985.HarryBeckandIhavereceivedcommentsbyrecipientsoftheinitialdraft. The enc)osed copy reflects those inputs. Sincerely, apr John Aspnes Principal Investigator JA:070985 Enclosure EES 84-29 INTERIM REPORT TO ANCHORAGE MUNICIPAL LIGHT AND POWER CHUGACH ELECTRIC ASSOCIATION,INC. FAIRBANKS MUNICIPAL UTILITIES SYSTEM GOLDEN VALLEY ELECTRIC ASSOCIATION,INC. DYNAMIC STABILITY STUDY OF THE ANCHORAGE-FAIRBANKS INTERCONNECTED POWER SYSTEM by John Aspnes Harry Beck Institute of Water Resources/Engineering Experiment Station University of Alaska-Fairbanks Fairbanks,AK 99701 May 1985 INTRODUCTION A dynamic stability study of the Anchorage-Fairbanks interconnected power system was funded by Anchorage Municipal Light and Power,Chugach Electric Association,Inc.,Fairbanks Municipal Utilities Systems and Golden Valley Electric Association,Inc.,in 1984.The study was to be performed by Electrical Engineering Department personnel at the University of Alaska-Fairbanks (UAF). One utility,Chugach Electric Association,Inc.,required this interim report as a condition for its participation. Project tasks include: Complete review of system database as developed by previous studies and used by utility engineers and their consultants. Five case studies most significantly impacting total system stability as determined in consultation with Anchorage-Fairbanks Intertie Committee. Initial system power flow conditions for all test cases as a check against results from previous studies and as an aid in determining future system operating conditions. On-line computer model of interconnected Anchorage-Fairbanks power system to reside on University of Alaska Computer Network.This statewide system can provide ready access to the model for additional studies by participating utility engineers throughout Alaska. Technical consultation on all aspects of project relating to system power flow,transient/dynamic stability,reliability and operation. Final report completely documenting system model,results and analyses of test cases and recommendations on system operation. The database provided by Gilbert/Commonwealth was to be used in the interest of reducing stability study project cost. -1- Complete relay data and recent load data were not made available in the Gilbert/Commonwealth "Alaska Railbelt Interconnected Electric System Data Book."If these data can be provided in a timely manner by the railbelt utilities,we fully expect to include such data in the final report. Nine representative stability cases involving line faults or equipment failures have been chosen for study.These are described on page 9 of this report.The cases were selected as being most likely to cause system instability.The ability of static var systems (SVS)to enhance stability was also of interest.Thus,four of the cases provide a direct comparison of SVS impact on system response to a specific fault or equipment failure. DATABASE A-computer model of the interconnected Anchorage-Fairbanks electric power system has been created.The transmission system data of the interconnected Anchorage-Fairbanks power network used in this model was collected during the period 1980 to 1984 by Gilbert/Commonwealth for the purpose of performing system studies relevant to the construction of the Intertie.The information has been checked for accuracy by Electrical Engineering Department personnel at UAF. This investigation into the accuracy of the database developed by Gilbert/Commonwealth was conducted last year.Although the best available at the time,some data acquired by Gilbert/Commonwealth from previous studies and contained in their database were found to be out-of-date.The investigation showed differences between the data reported by the utilities and those used by Gilbert/Commonwealth in their system model. Included in the Appendix of this report are review comment letters to the utilities identifying those differences.These letters were forwarded to Gilbert/Commonwealth for their use in updating the information contained in the system database.However,the information contained in the comment letters was not included in the Gilbert/ Commonwealth report to the Alaska Power Authority (APA)titled "Alaska Railbelt Interconnected Electric System Data Book." The most difficult and time consuming task in performing a system stability study is assembling and verifying the information that forms the system database.Detailed data concerning the generators,exciters, stabilizers,governors,turbines,transmission lines,transformers, shunt devices,substation loading,relaying,load shedding,unit commitment,intertie power exchange agreements and normal utility operating conditions and practices,for example,must be accurately reproduced in the database if meaningful and relevant results are to be expected. In most cases it is not possible to obtain all data necessary to perform a stability study without special inquiry being made.For example,data taken from manufacturer's bids are limited in scope and these are often the only known data for a machine.Thus it is often necessary for the engineer to estimate or assume the missing information.With respect to this project,most of the generator data required for the stability study were obtained while most of the exciter and governor data were missing or unavailable.In these instances, Gilbert/Commonwealth provided representative data for system modeling and inclusion in their data book. The database for the interconnected Anchorage-Fairbanks power network is currently stored on a VAX 11-730 at the UAF Engineering Experiment Station.The database is being made consistent with the information presented in Gilbert/Commonwealth's report to the Alaska Power Authority,"Alaska Railbelt Interconnected Electric System Data Book."Once this database modification is complete,it will be transferred to the University of Alaska Computer Network's VAX 11-780. The database will then be made available to those utilities participating in this study.The acquisition,verification,and computer entry of data necessary for this study were easily the most complex and time-consuming processes associated with this project. STATIC VAR SYSTEMS Static var systems (SVS)are installed at three locations along the intertie;the Teeland,Healy and Gold Hill substations.They provide var generation under heavy tie line loading and absorb excess line charging vars under light loading conditions.Voltage control is provided on a three-phase basis with voltage fluctuations reduced to less than 0.05 per unit. SVS MVAR output is defined as positive (+)for capacitive operation and negative (-)for inductive operation.The SVS ratings for each of the substations are indicated below: TABLE 1 -INTERTIE SVS RATINGS Substation kV MVAR Inductive Capacitive Gold Hill 13.8 -5 +33 Healy .13.8 -33 +22 Teeland 13.8 -22 +22 The static var compensating systems installed along the Anchorage-Fairbanks Intertie are being analyzed to determine their effect on system operation.Potential operating problems caused by disturbances to the system are being analyzed using the computer model to determine their effect on the transient/dynamic stability of the system, The individual SVS is modeled as a thyristor controlled reactor (TCR)in parallel with a capacitor of fixed value.The SVS is then connected to the appropriate winding of the SVS transformer.The slope of the SVS control characteristic curve is the change in SVS output reactive power divided by the change in bus voltage.This change in bus voltage (V)is defined as the SVS-controlled bus voltage minus the -4- reference setting or normal operating bus voltage.The slope referred to above is called the control slope (1/R)and,within the linear range of operation,R is on the order of 3-5%. The transfer function of the SVS provided by General Electric Co. (G.E.),the manufacturer of the device,is: G(s).Y(s =-e5 T dX(s R(i +sT)) where Y(s)is the SVS output in per unit (p.u.)vars on the device base, X(s)is the SVS input V in p.u.volts as defined above,Ty and Ln (in seconds)are the SVS time delay and time constant respectively,and R as defined above.The values chosen by G.E.for these variables in their transient analyzer study of the systems were:(1)R =0.05,and (2)Ty =0.150 seconds.The time delay,Ty:has a value of 0.002 seconds. The SVS has the capability to change its output susceptance from full capacitive to full inductive within three cycles.Examination of the transfer function,G(s),above shows that the SVS would respond faster to voltage changes on the controlled bus for a time constant value,Ty of three cycles (0.048 seconds)as opposed to the value of 0.150 seconds as specified above.For the model of the SVS used in the preliminary case studies,Ty was selected to be equal to 0.048 seconds. The SVS model used in the preliminary case runs was made more responsive to system disturbances in order to determine if deleterious system conditions would develop due to its operation.The SVS model used is identical to that in the Gilbert/Commonwealth case studies in that they both utilize the same transfer function.The transfer function uses a time constant,Ty of 150 msec upon recommendation from the device manufacturer.In the UAF studies this time constant was set to 48 msec (three cycles)to observe the effect of improved response time upon system operation.This significant lowering of the time constant was done for experimental purposes only.Only the equipment manufacturer,G.E.,could assess whether,in fact,this time constant value is physically realizable and operationally desirable. Preliminary results from stability cases found some objectionable aspects of SVS operation.While the SVS acted to promptly restore SVS controlled bus voltages to the normal range of operation following a -5- disturbance,no significant improvement in system transient stability response was noted for the cases studied.In addition,significant hunting among the devices was evident.For all of these stability cases the power flow initial conditions assumed 45 MW export North. A significant weakness of the EPRI stability program is that it has no provision for modeling static var systems.To fail to accurately model the SVS in studies of the Intertie could result in serious errors occurring in the analysis of power system stability response.It was, therefore,necessary to model the SVS separately from the stability program.At each time step,voltages at the SVS-controlled bus were examined to see if they were within the range of normal operating voltage at their respective buses.If not,a var adjustment calculation was made and the shunt susceptance at the SVS controlling bus was changed in the stability program by the inclusion of a system modification card in the control card deck.This control card contains the value of shunt susceptance calculated and the time into the simulation that the adjustment is to be made.The simulation then continues from this point.This process proved to be tedious and very time consuming but was required for the accuracy necessary in determining the system response. It remains to be seen whether the static var systems actually being installed along the Intertie will perform as well as the model used in our preliminary studies.Since the regulator time lag (T)value of 0.150 seconds as established by the device manufacturer is much larger than that used in the preliminary case studies (0.048 seconds),it is obvious that the response of the actual SVS devices will be slower than that of those studied here.We recommend that the Intertie Operating Committee request from G.E.copies of the stability analysis that concluded with the determination of 150 msec for the time constant,Th» and explore whether this value can be stably lowered for improved system performance. In the final stability case studies that UAF will conduct,the time constant,Ths will be set to the value recommended by G.E.Those cases are as identified.Also,the 1%deadband used in our preliminary cases is expected to be changed to reflect actual operating practice.A recommended 5%deadband is obviously too wide,approaching the line -6- limits.The present Gold Hill SVS setting of 2%might be the best compromise.It is strongly recommended that the Railbelt utilities further investigate the SVS performance relating to system stability improvement after the Intertie is in operation and a sufficient history of reliable service has been established. STUDY The Electric Power Research Institute (EPRI)software being used for our research includes the power flow,stability and plotting programs integrated into the single package necessary to perform this study.The software was compiled and the cases prepared for this study were processed on a Digital Equipment Corporation (DEC)VAX 11-730 at the University of Alaska Engineering Experiment Station located on the Fairbanks campus. Disturbances to the system are being analyzed using the computer model to determine their effect on the transient/dynamic stability of the system.To perform a stability study,the following data are needed: 1.A power-flow study of the network detailing the initial conditions present prior to the disturbance. 2.System data describing in detail the generators and their control equipment,protective relaying,load shedding and the load representation. 3.The location and nature of the disturbance,time of switching and system modifications,and the maximum time for which a solution is to be obtained. The power flow cases must represent relevant combinations of generation dispatch,substation demand level and intertie power flow conditions with normal system configurations.The SVS model should provide continuous control to maintain controlled bus voltages.The -7- acquisition,verification,and computer entry of all data necessary for a stability study is the single most important process associated with this work.: The EPRI Power Flow program initiates the stability study by providing the steady-state operation point at time zero.The stability program simulates the dynamic response of the power system for a variety of operational disturbances.The principal function of the program is to determine the power system stability for the prescribed disturbance. For power systems,the most common disturbance that is studied is the three phase fault.The behavior observed immediately after a disturbance is applied to the system under study can be characterized by severe machine oscillations that can result in system breakup or loss of synchronism among units.If any generator rotor angle exceeds 360°or if the oscillations in system variables such as bus voltage or generator velocity deviation grow without bound or are sustained indefinitely,the system is considered unstable and the study is terminated. The first step in the stability calculations is to solve for the initial load flow in the system to determine the initial conditions of bus voltages and power flows in the system.The next step is to apply the disturbance and again solve for the power flows under the new circuit conditions.Comparing the results of these steps will give the difference between the driving torque on the rotor and the electrical load torque for each generator.This difference is the net accelerating torque on the machine rotor.Since the rotor inertia is known,the angular change in rotor position for a given time step can be calculated.Calculations are continued until the stability characteristics of the system are determined.The result is a swing curve in which the angular position of each rotor is plotted as a function of time.From the swing curve an indication of the stability of the system can be determined under the conditions imposed. Since the torque or power equations for the synchronous machines are nonlinear,some appropriate step-by-step method of solving nonlinear equations is used.The stability program solves the power system equations using the Newton-Raphson iterative technique.A suitable time step is selected.The shorter the time interval selected,the more accurate the results and,obviously,the greater the number of -8- calculations that are performed.This necessitates the use of an extremely fast computer system with a large amount of on-line memory to store the results of these calculations.The Digital Equipment Corporation VAX 700 series of computers is ideally suited for the simulation of these large scale electric networks. There are two basic types of disturbances that can be applied to a system when analyzing stability are line faults and equipment failures. Nine representative cases from both categories have been preliminarily chosen and examined to determine their impact on the stability of the interconnected power system.These cases are identified below. CASE DESCRIPTION CASE NO.DESCRIPTION 1 Loss of Healy SVS 2 Fault at Pt.Mackenzie 138 KV -10 cycle clearing -SVS on-line 3 Fault at Pt.Mackenzie 138 KV -10 cycle clearing 4 Loss of Healy generator -SVS on-line 5 Loss of Healy generator 6 Intertie open circuit at Teeland 138 KV -SVS on-line 7 Intertie open circuit at Teeland 138 KV 8 Fault on intertie midway between the Douglas and Teeland substations -SVS on-line 9 Fault on intertie midway between the Douglas and Teeland substations It has been found that those disturbances that are most likely to result in system instability are line faults.Rapid fault clearing is still considered to be the single most important factor in maintaining system stability.Since faults lasting longer than nine cycles are very likely to produce instability,10 cycles was used as the basis for fault clearing times for this study. Unless the Intertie Operating Committee has alternative cases that they would like us to examine,we will repeat our stability studies based upon the cases that we have preliminarily examined.These final case studies will accurately reflect the system one-line diagram as presented in the Gilbert/Commonwealth data book issued this year.The function parameters of the SVS will also be as given in the data book. A great amount of time was spent by the Electrical Engineering Department at UAF debugging the EPRI software and documentation.In addition,considerable time was spent compiling the source code to produce the executable image that we use in our power flow and stability case runs.It is these executable image files that the utilities will use to run their own case studies.A significant weakness of the EPRI code is the lack of an SVS model for simulation.We investigated the possibility of modifying the code ourselves to rectify this conditions. In discussions with industry experts,we were advised not to attempt to modify the code due to the enormous complexity of the task and the magnitude of the time that would be required. We are presently arranging with the EPRI Software Service Center to purchase copies of the EPRI documentation for the power flow,stability and plotting program software for distribution to utilities participating in this project.This documentation consists of EPRI Power Flow Program User Manual and EPRI Transient-midterm Stability Program and Plot Program User Manual.For those utilities requesting copies of these manuals the cost is $25.00 each. -10- February 11,1985 M.L.G.Miller,P.E. Gi lbert /Commonwealth 209 E.Washington Avenue Jackson,Michigan 49201 Dear Mr.Millers As requested by the Intertie Operating Comaittees,ne have reviewed the "Alaska Railbelt Interconnected Electric System Data Book”and have furnished our review comaents to you.The data book,however ,only contained relay information regarding underfrequency load shedding.No data were listed regarding distance,over-voltage,cut-of-step blocking,resote relaying or -power relays.In addition,no information was listed concerning the relaying employed along the Intertie as designed by Gilbert/Comaonweal th., We have been requested by the member utilities of the Intertie Operating Comaittee to build a database for the interconnected Anchorage-Fairbanks power system based upon the data provided to you by the Railbelt utilities.Would you please provide us with any additional information regarding system relaying as identified above not contained in your original data book described above. Thank you. Sincerely, John Aspnes,P.E.,Head Department of Electrical Engineering 233 Duckering Building University of Alaska Fairbanks,Alaska 99701 (907)474-7137 cc:David Eberle,Alaska Power Authority Bob Orr,Intertie Operating Committee Harry Beck,University of Alaska DP317 10 Auguat 1984 Mr.Jokn MarshallChugachElectricAssociationDepartmentefEngineeringP.O.Bex 3518Aacherage,Alaska 99501 Dese Jon, I hewe reviewed the machine,exciter,governor and turbine data as submittedbyCommonwealthAssociatesattheJuly11,1984,masting ef the ReliabilitySubcommitteeoftheIntertieOperatingCommittee.My review comments arenetedbelow. The fellowing sachines have inpedances that are much larger then that ofrepresentativemachineshavingthesameoperatingcharacteristicsandmachineratings.The impedence(s)ere listed after the mechine uname: International#1 and #2 -Xd,X%q and XlInteraational#3 -X4 Statica |fl,#2,#3 -Xd,x'd,Xq and XlBerniceLake#2 -xl Beluga #8 .-Xd end X%q The following machines have impedances that are much smaller than that of representative machines having the same operating characteristics and machine Tatings.The impedance(s)are listed after the machine name: International #3 -Iq Eklutna #1,#2 -Xd and Xl Cooper Lake #1,#2 =Xd,xX'd,Xa.X'q The following machines sre not represented with machine,exciter,governor and/or turbine data: Bernice lake fl Bernice Lake #2 Exlutna #1,#2 Station 1:#1,#2 Beluga #8 Cooper Lake #1,#2 International #1,#2 The following comments apply: a.Armature resistance data is missing for all machines; b.Exciter model type |is not an exact representation of EPRI model type EA;c.Time constants TA and TAl used in exciter model type 1 have assigned values that are self-cancelling; d.Exciter data ia not exact but merely representative making its use questionable as far as adequacy and accuracy of the final system mdel ia concerned; e.Commutating reactance data for all type 3 exciters is missing; Review of Data ;10 August 1984 Page 2 f.All GE generators in the CEA system are modelled with CZ type SCPTtypeexciters.These generators were installed over a 17 year periodmekingthelikelihoodthattheyallutilizethesametypeofexciter with the same response characteristics highly improbable. g-Regulator limits for the exciters used with the hydroturbines appearerroneous;h.The type 2 steam turbine and governor representation is unnecessarilycomplexasasumberofthefunctionblocksareself-cancelling.It ismotspparentthatthisisasuitablerepresentationtobeusingforcombustionandhydrotypeturbines. If yeu have avy questions concerning this review,please contactmeateither474-7137 er 452-2709. Sincerely, : .;- Harry L.Beck,Research Assistant Dept.of Kleetrical Engineering 233 Duckering Building University of Alaska Fairbanks,Alaska 9970! HB:4G:21/11 28 August 1984 Dr.F.S.Prabhakara Gilbert /Commonwealth 209 €&.Washington Avenue Jackson,Michigan 49201 Dear Dr.Prabhakara: I am glad that we had a chance to talk with one another in Anchorage last week.I have been impressed with the concern for accuracy and adequacy that Gilbert/Commonwealth has oO 2sdisplayedinthepreparationoftheirsystemstudiesforthete” Anchorage-Fairbanks Intertie Project.To that end,we have been " reviewing your work and the material furnished us by the utilities.Once we have completed our review of this. information,we will pass our review commentson to you. "&S you requested I have enclosed the review comments that we've previously sent to the utilities following review of the data of their respective systems.I did nat indicate any actual data values in this review as I meant only to highlight areas of concern that the utility reviwer should further explore.He would then determine for himself if the errors in the data were of significance. Since you indicated at the August 23,1984 Intertie Operating Committee meeting that Gilbert/Commonwealth would be using the EPRI 745 stability program for your transient stability study,would you please tell me how you will modify the program to allow for the modelling of the static var systems.I am extremely interested in the modelling of these systems and will be interested to see the approach that you've chosen. I look forward to hearing from you and wish you much success with your project. Sincerely, Harry tL.Heck,Research Assistant Dept.of Electrical Engineering 253 Duckering Building University of Alaska 'Fairbanks,Alaska 99701 30 July 1984 Homer Electric Association 3877 Lake Street Homer,Alaska 99603 Dear San, As proaised,I have reviewed the line and load data for your system assubaittedbyCommonwealthAssociatesattheJuly11,1984 meeting of the Reliability Subcommittee of the Intertie Operating Committee.My Teview comments are notad below: The following substations were shown to have winter 1984-'85 demand projections different from those calculated by HEA for the same period: Kenai Fritz Creek Soldotna Bernice 69 kV Homer Kastloff Anchor Point Bernice 25 kV Tesoro Bernice 4 kV The following transformers and line sections were shown to be incorrectly modelled or to have per unit impedances and/or charging susceptances different from those indicated in the recent HEA sectionalizing study prepared by Miner &Miner. Bernice -Soldotna Bernice -Tesoro Soldotna -Kasiloff Kasiloff -Anchor Point Anchor Point -Diamond Ridge Diamond Ridge -Homer Diamond Ridge -Fritz Creek Soldotna -Kenai Soldotna 69 kV -115 kV Diamond Ridge 69 kV -115 kV Bernice 4 kV -24.9 kV -69 kV Would you please provide me with a copy of the review comments that you send to Commonwealth Associates for their aid in the preparationoftheRailbeltElectricUtilitySystemDatahandbook.Thank you. Sincerely, Harry L.Beck,Research Associate School of Engineering 233 Duckering Building University of Alaska _Fairbanks,Alaska 99701 907/474-7137 lo July 1984 Mr.John Marshall Chugach Electric Association Department of Engineering P.O.Box 3518 Anchorage,Alaska 99501 Dear John, As promised,I have reviewed the line and load data for your system as submitted by Commonwealth Associates at the July 11,1984 meeting of the Reliability Sub- committee of the Intertie Operating Committee.My review comments are noted below: The following substations were showa to have winter '84-85 demand projections different from those calculated by CEA for the same period: International University Indian Girdwood Daves Creek Portage Beluga Hope Bernice Lake The following transformers and line sections were shown to be incorrectly model-ed or to have per unit impedances and/or charging susceptances different from those indicated on the CEA positive sequence impedance diagram -1984: Beluga?13.8 -Beluga 138 Beluga8 13.8 -Beluga 138 Beluga 138 <-Beluga 230 Bernice3 13.8 -Bernice 69 Bernice 69 <-Tesoro 69 Bernice4 13.8 -Bernice 69 Intnl.138 -Pe Wefl 138 Intnl.138 Pt.Wzf2 138 Beluga 230 -Pt.Mkz 230 Pe.Mkz 230)=Pt.Mkz!l 138 Teeland 230 <-Pt.Mkz 230 Pt.Mkz 230)1 -Pt.Mkz2 138Soldtn.69 -Kenai 69 Qtz.Cr.69 -Cpr.Lr 69 Univ.34.5 <=115 -138 Univ.230 -Univ 138 Univ.230 -Pt.Mkz 230 Bernice 4.16 -24.9 =69 Daves 69 -Daves 24.9 Daves 24.9 -Seward 24.9 a.The shunt reactor at E.Terminal 230 is not modelled; b.Rated power for all generators is not correctly specified. Would you please provide me with the winter and summer dispatch schedule for all generators including scheduled power and vars,operating output voltage,droop setting,and if under antomatic generation control (AGC).The interchange power flow agreements between CEA and other utilities would also be extremely helpful. I have started to review the machine data for your system.After this review,1willagainforwardmycommentstoyou.Thank you for your assistance. Sincerely, iHarryL.Beck,Research aselatant233DuckeringBuilding 18 July 1984 Mr.Ken Ritchey Matanuska Electric Association Department of Engineering Palmer,Alaska 99645 Dear Ken, As promised,I have reviewed the line and load data for your system as subaitted by Commonwealth Associates at the July 11,1984,meeting of the Reliability Subcoumittee of the Intertie Operating Committee.My review comments are noted below: 1.The following substations were shown to have winter '84-85 demand projections in excess of 10%above those calculated by MEZA for the same period:Anderson Settlera Bay O'Neil Reed Site Bay Camp 2.The following substations were shown to have winter '84-85 demand projections in excess of 102 below those calculated by MEA for the same period: Lucas Shaw Douglas Herning McRae Briggs Pippel Lazelle 3.The following line section vere shown to have per unit impedances and/or charging susceptances in excess of 10Z above those recorded by MEA: 1822 1825 1826 1830 4.The following line sections were shown to have per mit impedances and/or charging susceptances in excess of 10%below those recorded by MEA: 1801 1802 1804 1807/1808 1821 1823 1824 1830 5.The following line sections were not modelled correctly (e.g. substation located at its tap): 1806 1827 1828 1829 Would you please provide me with the following information/material: a.Impedances of the Pippel,Reed,&Palmer substation transformers b.Impedances between the taps and the transformers for the Pippel, Reed,&Palmer substations c.Winter '84-85 projected demand for palmer substation d.Amended one-line diagram (basic)of the Teeland substation after 230 kV conversion with transformer &line impedances shown e.a complete copy of the review comaents you make to Common- wealth. Thank you for your assistance, bo OO Harry L.Beck,Research Assistant wR.we 7.1A es8agenute©peeseeeeeteoe.aSieOe.-"teelrical Engineering Department UNIVERSITY OF ALASKA.FAIRBANKS Fairbanks,Alaska 99701 sul 2 yaR4 POWER AUTHORITY 27 June 1984 Mr.David Eberle Alaska Power Authority ALASKA 334 W.Sth Avenue Anchorage,Alaska 99501 Ley Dear Mr.Eberle: We are presently building the data base for a dynamic stability study of the Anchorage-Fairbanks interconnected power network.The most important requirement of providing a highly accurate study is the model representation of the system.System stability depends on characteristics of all elements of the power system.This includes the response characteristics af the turbogenerators and their control equipment,the dynamic characteristicsaf the loads,and the device types and settings af the protective equipment used. To ensure that our computer model is the most accurate representation of the network to date,we have requested from the Intertie user utilities,data that describe their power systems transmission lines,machinery, control and protective equipment,load information,and operating guidelines.All Utilities that we contacted experienced no difficulty in providing us with the requested information with one notable exception. exception is the generator and control equipment exciter,governor,turbine,stabilizer)response characteristics.In this area,the data that the utilities have provided are lacking.' That (e.q. We are aware of efforts by Commonwealth Associates to acquire this same information from the utilities and from the generator manufacturers.We don't know,however, how successful they were in obtaining this data.I would like to have you request that Commonwealth provide us with UNIVERSITY OF ALASKA the data that they used in their stability study including any assumptions that were made in instances where this information was not available. Tl appreciate your assistance. Sincerely, CYatty RX.Geck Soe, John Aspnes,F.E. Dept.of Electrical Engineering 235 Duckering Building University of Alaska F Fairbanks,Alaska 9?701 907/474-7137 Bod (a $: ex oR TELECOPY g,Gilbert /Commonwealth engineers and consultants Gil.BERT /COMMONWEALTH iNC.OF MICHIGAN,209 E.Washington Avenue,Jackson,MI 49201/Tel.$17 788-3000 July 9,1985 APAI-20611 .Mr.D.R.Eberle Alaska Power Authority 334 West 5th Avenue Anchorage,AK 99501 Dear Mr.Eberle: SUBJECT:ALASKA POWER AUTHORITY RE: ANCHORAGE-PAIRBANKS INTERTIE PROJECT TEELAND SUBSTATION 230 kV UPGRADE APA LETTER OF JULY 3,1985 CHUGACH LETTER OF JULY 2,1985 In response to your letter of July 3,1985,I have asked John Morrison and Dave Shafer to review the information submitted together with Chugach's letter of July 2nd.Their comments follow: TEMPORARY EMERGENCY 138/115 kV TIE AT TEELAND SUBSTATION The proposed connections for the 138/115 kV transformer will not adversely effect APA equipment at Teeland Substation,if CEA implements the following measures: 1. 2. Provide adequate transformer and 115 kV line relay protection. Install surge arresters on both 138 and 115 kV sides of the transformer, if not already existing. Keep the SVS equipment at Teeland,Healy and Gold Hill,and the intertie in service during this period.This is required to minimize the need to restart the SVS's and the intertie under weak system conditions. Limit power transfer over the intertie to 30 MW under this circuit arrangement.Refer to Engineering Report R-2729,June 1985. "Anchorage-Fairbanks Intertie Transmission Loss Study”. We trust this answers your questions concerning the Chugach plans. Yours very truly, ZB; eG,Miller,P.E. oject Manager LGM/lje S28 Lancaster Avenue,Reading,PA/Margantown Road,Groen Hills,Reading.PA 21S 775-2609 209 East Washington Avenue,Jackson,Mi S17 788-3000 Ms,*Rrsoikg#ay:atedin'Blectrical''Engineering |«Chugach:Electric Association,.Inc.P20.Box 6300©"Anchorage,AK 99502"SUBJECT:"Teeland 'Substation Upgradeto 230kV.Teaporary,Emergency Supply Connection -In responseto your letter of.duly 2.1985 regarding subject|.Temporary Supply Connection,I have asked our Design.Engineer,-St lbert/Commonwealth,to.review your proposed plan...Melbay"be advised that the PowerAuthority.has no objectionto'Chugach's proposed plan,providing.that CEA complies with.the ©four:precautionary-measures "and:restrictions ©outlined =in"Gilbert /Commonwealth's letterof uly 9,1aAlcsRDMnteeediBNEAAaeMle2alana enceeme qm ELECTRIC ASSOCIATION,INC. 5601 MINNESOTA DRIVE @ P.O.BOX 6300 *ANCHORAGE,ALASKA 99502-0300 »PHONE 907-563-7494TELEX:CHUGACH AHG (090)25 265 TELECOPIER: 907-564-0632 July 2,1985 Alaska Power Authority 334 West 5th Avenue Anchorage,Alaska 99501 Attention:Mr.David Eberle Subject:Teeland Station Upgrade to 230kV Construction Gentlemen: Enclosed is one copy each of the single line diagrams ("before" and "after")and the proposed emergency supply connection as discussed during our telephone conversation on July 2,1985. The emergency connection between Matanuska Electric Association's (MEA)115kV system and the Intertie would allow supply to MEA via the Intertie if the tie to Anchorage via Eklutna should fail.It would also make a certain amount of power transfer to the Intertie possible,via the MEA system. Construction is scheduled from August through October of this year with extensive outages on the 138kV system expected during the early phases of construction,when the transmission line between Point MacKenzie and Teeland is upgraded. The station upgrade contract will bid on July 11,1985 and the transmission line conversion is scheduled for bid on July 22, 1985. We will make contract documents available for your information by July 9,1985. Sincerely, ronC-Wavte2Q_- ohn Marshall,P.E. Acting Director -Electrical Engineering Enclosure ce:M.Tullius w/o encl. 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"XN / SO a ;TO CEA 140 KV DEAD END : pe”- TO OxioTina 16 KV ' CORNER STKICTURE ©© SE STREetes oe Se 8 a agit PE RYpetetopts, 119 wv Ne Ay NOTE: POR ASSEMSUL UNIT DETAILD,E.6."TM-1344SEECAHIBITSBOARDRITHTHESPEGFCAONS. ACRES EEE REE ' :®) SECTION (TY " SCALet=$097.\-/ ® ..moe we ete n ..o DG aw INSMeMORRISCN-KNUDSEN ENGINEERS,INC,TEELAMS 2300418.kV SUBSTATION 4705-16-T1 : O \esx/95|Couto wot wT IP BIO”tao weet,ance 08,a sao 'vo wa wo es es Soe a :bone 1 +:TEMPORARY,inte<D x ”7 ied +SLAM PESOS 6 7)2%-03sd ..aa Soston a Fe cce Th aE eT ennae er ee he sey S A fnes|ioneo08caerk CATER ARO ae ee io '|GTRANSMISSION-TIESLINES fener 2 woaGeen¥Smit 34.5 KV ©fo.iw) '? Busnaa caney3TROJGH " PY)etl -_Sy CONT ROA, Bude.600)a,-aeHOREOwOSooo? LEGEN 3B-AV OCB TO BE REVSED on SITE. {21-kV CCH FO Be KEUSEP ON SITE. {DO-kv OCB'DS to ft REWIVED To INTERNATIONAL NARE HOUSE(REMOVE S.P D'S BEMORE TRANSHORTING.- 15-kV PT's To BE REUSED. {DB-kV ROVER PT TO BE REMO.TD TO INTERNATIONAL WAZE HOU {tO 115 EV TRANS TORMER To BE USED FOR TEMROZARY Tit anoTHENTRANERORTIDTOWTLEMATIONALWAREHOUSE. 198-94.54V TRANSFORMER TO BE KEMOVED TO |KTER NATIONAL °HAPE ROUSE, 115-S45bhV TRANSROKMER TO BE REMOVED TO INTER HATIONAL,NAEEROUTE, 115-S4BkV TRANSFORMER TO BE REMOVES TO INTERNATIONALWAREHOYOE. WSEV SPOLE DeCONNOT *HITOESBBE REMOVED (4)FO INTERNATONAL.MARE HOUSE a5 PT's (2)To BE REUSED DBSKV DECONNET SwiTCHES(9)Jo BE REUSED NOTES THIS PRAWING 1S FURNISHED FOR THE CONTRACPI" INFORMATION.ALL ITEMS ON IHD PRAnDG ARE EXIPTING. Z.AL NEW CONSTRUCTION 19 To BE BUILT FELATNE 72 THE INPICATED REFERE Mee CENTER LINES eu AFP ROKMMTE LOCATION Of 173/115 KVTRANSRAMERFORTEtAeYTIE,SEE DK,4-708seatsssi cyir)xyls ;aer7eea ee eeersore By al we fuk vaterece(OPED1¥A7aA VAKV DAILAS LINE / P {--_----___F __=2 4 CRNEee- +--] B Lbetsof ee ED ER Se ID As a/ee las LA It:4 [SDUES WOR Con Cort natl AP RoaSG?Ey jet tee SITAR 15.SB STS AMAMMBANE 21 ARK MORRISON-KNUDSEN ENGINEERS.inc,|CHUGACH ELECTRIC ASSN.,INC.| TEELAND 230/115 kV SUBSTATION -[/"***" a www 2 OEE COmr any ,}4705-16-12 ABCTC OFNTRICT iOLDSTELET,APCOPAGE,Basen CO900 5 Powe Bed 1639!270-013!\EXISTING ARRANGEMENT aae|TES SNES,fOPAEM ey CRECHED RATS 0"8 u |B et ve 4704 ® -Municipal Light &Power 1200 EAST FIRST AVENUE -ANCHORAGE,ALASKA 99501-1685 TELEPHONE (907)279-7671TonyKnowles, Mayor RECEIVED June 17,1985 JUN 19 1985 Alaska Power Authority ALASKA POWER AUTHORITY 334 West 5th Avenue Anchorage,AK 99501 Attention:Mr.Edwin L.-Morris Subject:Interim Operating Budget for the Interim Intertie Agreement Dear Mr.Morris: Please find attached both an interim and an annual operatingexpenseestimateforthesouthernintertiecontroller. I have appointed John Cooley as Acting Manager of Power Management for ML&P and as such he will be the contact person with whom to discuss budget details for the intertie. Sincerely ae Thomas R.Stahr General Manager Municipal Light &Power ors /Ste/csn attachments CC.Eka;hoe Khan ESsefe | TA scke PROVIDE FOR TOMORROW,SAVE ENERGY TODAY. INTERIM OPERATING EXPENSE OF THE SOUTHERN INTERTIE CONTROLLER The interim expenses through September 1985 are based upon ML&Ps pro- jected annual operating expenses reduced as indicated below.The following is a summary of these costs: Operation Labor $71,859.00 DEC Maintenance 838.00 Operating Committee Costs 4,451.00 Operating Expense SCADA 13,104.00 Total $90,252.00 Following are the details of how the annual budget was modified to obtain the interim expected expenses. Operation Labor Assuming actual power transfers will be taking place by the end of July,two months of the annual operating expense was included. 2/12 of $358,775 =$59,796 In addition,the following personnel expenses are included to cover development of schedules,reviewing of switch orders and switching for testing and startup of the intertie during June and July. Hours Cost/Hr. Division Manager 80 $54.53 $4,362 Chief Dispatcher 80 51.26 4,101 Dispatch Consultant 80 45.00 3,600 12,063 DEC MAINTENTANCE The SCADA computer is expected to be on-line by the end of July so two month of the annual operating expense was included. 2/12 of $5,028 =$838 'OPERATING COMMITTEE COSTS The interim period is expected to be three months so one quarter of the annual operating expense was included. 1/4 of $17,805 =$4,451 OPERATING EXPENSE SCADA The SCADA system is expected to be complete by the end of July so two months of the annual operating expense was included. 1/12 of $78,627 =$13,104 ANNUAL OPERATING EXPENSES OF THE SOUTHERN INTERTIE CONTROLLER Anchorage Municipal Light and Power has been designated as the Intertie Operator for the Southern Control Area,per the Anchorage-Fairbanks Intertie Agreement.ML&P will be paid by APA for this service. Following is a summary of those costs: Operation Labor $358,775 DEC Maintenance 5,028 Operating Committee Cost 17,805 Operating Expense SCADA 78,627 Total $460,235 Following are the details of how the total costs were derived.The costs are categorized by type of function required to operate the intertie in the most reliable,economic manner.It is broken down by hours per day and by total hours per year.The functions required are based upon past experience in the Anchorage area and the current ver- sion of the Anchorage-Fairbanks Intertie Contract. Required Time Function Per Shift Per Year *Dispatching l.Monitor Status &Perform Control 1.0 hrs.365 2.Review Modify &Correct Transactions -5 hrs.182 3.Review Transactions (Including Reserves VS Actual Operation -5 hrs.183 4.Review &Correct for Load Flows -5 hrs.182 5.Record Keeping -5 hrs.183 6.Ongoing Training Program (Maint.Efficiency)-25 hrs.391 TOTAL 3.25 hrs.1,186 Required Time Chief Dispatcher Per Day Per Year l.Power Brokering for Others 1.0 hrs.260 2.Scheduling -5 hrs.130 3.Review Transactions &Sales -5 hrs.130 4.Account Reconciliation 1.0 hrs.260 5.Reports -5 hrs 130 6.Ongoing Training to Maintain State of Art -5 hrs.130 TOTAL 4.0 hrs.1,040 *Time shown is for one Dispatch Shift; to obtain total time,multiply by 3. Page Two,Annual Expe Division Manager nse 1.Review,Meetings,Reports Contracts 2.0 Clerical 1.Records,Reports,Typing,Filing 2.0 Elec.Technician 1.Hardware Maint.,Repair,Modify,SCADA, RTUS,including Travel 10.0 2.Software Maint.3.0 TOTAL Accounting 1.Prepare Billing Monthly Maintain Records 20.0 2.Data Processing &Reports Generation 2.0 TOTAL LABOR COSTS (Straight Time) Function Base Rate Overhead Dispatcher 26.11 19.45 Chief Dispatcher 29.38 21.88 Division Manager 31.25 23.28 Clerk 14.18 10.56 Technician 26.11 19.45 Accountant 22.38 16.67 LABOR COSTS (Overtime) Function Overtime Rate Overhead Dispatcher 52.22 19.45 Chief Dispatcher 58.76 21.88 Clerk 28.36 10.56 Technician 52.22 19.45 Accountant 44.76 16.67 hrs hrs. hr/wk. hr/wk. hr/mo. hr/mo. 730 730 FulUIDnOoa) ]nTotal 45.56 51.26 54.53 24.74 45.56 39.05 Total 71.67 80.64 38.92 71.67 61.43 Page Three,Annual Expense SUMMATION OF LABOR COST Function Hours Dispatch 3,558 Chief Dispatcher 1,040 Division Manager 730 Clerk 730 Technician 676 Accountant 264 Total 7,801 *Includes All Overhead Cost/Hr. $45.56 51.26 54.53 24.74 45.56 39.05 DEC Maintenance *Total $162,102 53,310 39,806 30,798 23,691 10,309$358,775 Exhibit A of the SCADA agreement specifies certain costs to be reimbursed by APA.Item #3.5 is an operating cost and should be billed as such,rather than as one time cost. DEC Maintenance 25% of $20,112/yr.=$5,028 Operating Committee Costs Full Committee Meetings Cost/Hr.Hrs/Yr.Cost/Year Chief Dispatcher $51.26 80 $4,100 Division Manager 54.53 80 4,360 Travel (2 persons 2 trips) at $200 800 Sub Committee Meetings Chief Dispatcher 51.26 80 4,100 Dispatcher 45.56 80 3,645 Travel (2 persons 2 trips) at $200 800 TOTAL $17,805 Page Four,Annual Expense SCADA COSTS Cost/Year Depreciation .02x$393,137=$78,627 sas Distribution: T.Stahr M.Massin H.Nikkels G.Bowen J.Truskowski July 10,1985 ALASKA INTERTIE OPERATING COMMITTEE BUDGET FISCAL YEAR 1987 Amount Subcommittee Purpose 1)$20,000 Dispatch/Training 50%Training Materials 50%Operating Manual 2)30,000 SCADA/Comm/Meter Studies (such as) Composite Power Flow Data Link Loading 3)5,000 Handbook/Procedures Drafting and Supplies for Manual 4)10,000 Machine Rating Drafting Generation Standards Manual Generation Manual Review &Assembly 5)See 1)above Dispatch Scheduling 6)5,000 Reserves/Loadshed Outside Review and Coordination of Load- shed 7)-0-Relay Protection 8)101,399 Reliability/Criteria Post Fault Analysis and Data Base Upkeep 9)12,000 Full Committee Secretarial Services for Minutes and Typing/ Copying 10)See all above Budget $183,399 TOTAL BUDGET REQUEST UNIVERSITY OF ALASKA,FAIRBANKS Fairbanks,AlaskX%¥X44 99775 10 July 1985 Afzal H.Khan,Director Systems Operations and Engineering Alaska Power Authority 334 W.5th Ave.,2nd Floor Anchorage,AK 99501 Dear Mr.Khan: Enclosed is an interim.report for the project titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System." A draft report by the same title was sent to you on May 30,1985.Harry Beck and I have received comments by recipients of the initial draft. The enclosed copy reflects those inputs. Sincerely, Caperoa- John Aspnes Principal Investigator JA:070985 Enclosure Record Copy File #HME PRO 2-4 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE WEDNESDAY,JUNE 12,1985 (At Chugach Electric Association,Anchorage) Attendance: Ken Ritchey Matanuska Electric Association John C.Marshall Chugach Electric Association Ray L.Duncan Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Alan Martin Fairbanks Municipal Utilities System Sam Mathews Homer Electric Association Mike Massin Anchorage Municipal Light and Power Stan Sieczkowski Alaska Power Administration Harry Beck University of Alaska-Fairbanks Dan Rice Gilbert/Commonwealth Ed Morris Alaska Power Authority Afzal Khan Alaska Power Authority Howard Thacke Alaska Power Authority The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Chugach Electric Association Training Room. Bob Orr motioned that the minutes be adopted as written and John Marshall seconded the motion.The motion was approved unanimously. Bob Orr then recommended that the agenda be revised to include "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System"as Item I under New Business.No one objected to it. Under Committee's correspondence reports,Mike Massin noted that a letter is sent to Mr.Mike Kelly,Chairman,Alaska Systems Coor- dinating Council,regarding these two committees,Anchorage-Fairbanks'Operating Committee and Alaska System Coor- dinating Council. Bob Orr reported that he was not able to have a SCADA/METERING/COMMUNICATION Subcommittee meeting because members from CEA and ML&P could not make it,so that the meeting was cancelled.Bob Orr recommended to the Operating Committee to set up another meeting. Marvin Riddle gave a report on the Dispatch/Training Seminar.He noted that there were two sessions and the course was well re- ceived.Marvin Riddle furnished the Operating Committee a letter from Dr.John Aspnes,University of Alaska-Fairbanks regarding the seminar.; 9894/410 AFIOC Minutes June 12,1985 Page 2 Marvin Riddle also provided the Operating Committee a brief report on the Dispatch Scheduling Subcommittee meeting.This meeting was held on June 11,1985 at 9:00 a.m.at the Municipal Light and Power Conference room. John Marshall discussed the under frequency load shedding plan. John Marshall submitted to the Operating Committee an under fre- quency load shedding plan,which is attached. Afzal Khan provided a status update on the Intertie project.He indicated that there is a serious problem associated with startup of both Healy and Gold Hill SVS.For the last six months,the Alaska Power Authority is trying to find a solution to SVS startup problem but neither Gilbert/Commonwealth and General Electric is responding to Alaska Power Authority's request to come up with a solution/recommendation.He reported that the General Electric field engineer has finished the remaining work with Teeland SVS. Don Homer,Senior Development Engineer,General Electric,is in Healy to do more SVS testing because the SVS failed when started last time.The transmission line will be energized on June 13, _1985,but it could be delayed.CEA asked for another fly-by of the transmission line from Douglas to Healy before energizing.Ar-rdngements will be made to do this before energizing the line.He discussed the low bus problem at Healy and Gold Hill substation when asked by Mike Massin.The Alaska Power Authority is awaiting the outcome of the SVS startup problem.Both items could be doneatonetime.Afzal Khan reported that according to Westinghouse Gold Hill transformer will be ready for testing by the end of June 1985.The shipment is scheduled for July 3,1985.The installa- tion and testing will take place sometime in August 1985.Afzal Khan also briefly discussed the maintenance agreement and mainte- nance procedure manual.A meeting will be arranged with GVEA and MEA to finalize both items.Afzal Khan asked Ray Duncan about a letter from CEA regarding implementation of APA data link.Ray Duncan pointed out that Kevin Parson will be going to Palo Alto to meet SC&I,ML&P SCADA vendor.When he comes back,he will have a good idea as to the requirements. There were no visitor comments;however,Mr.Harry Beck from the University of Alaska Fairbanks did sit in as a visitor. The Operating Committee had no old business to conduct at the meeting. Turning to New Business,the Operating Committee recessed into a break from 10:10 a.m.to 10:25 a.m. Turning to SCADA/METERING/COMMUNICATION SUBCOMMITTEE,Bob Orr indicated that the implementation of data link is going along pretty good.He also noted that CEA,ML&P,and GVEA will be meeting with SCADA vendors in Palo Alto,California.Mike Massin 9894/410 AFIOC Minutes June 12,1985 Page 3 noted that ML&P will install RTU at Eklutna Power plant and he also indicated that someone from his office will be talking to the Power Authority regarding microwave link.Dan Rice discussed the adden- dum in the operating procedure manual.Dan Rice also discussed the loss tables and asked the participants to submit their comments by June 28,1985.To expedite the process,Dan Rice requested that the comments be telephoned or telecopied to him.Dan Rice suggest- ed updating operating procedure manual every six months.Mike Massin asked participants to come prepared to discuss operating procedure at the next meeting.The committee commended Gilbert/Commonwealth for the work done on loss tables. Marvin Riddle noted that there is not much to add on Dispatch- er/Training other than that which had already been mentioned. A very brief discussion took place on Dispatch/Scheduling.The use of Intertie and cost to recover were discussed. Turning to the Reserves/Loadshed,John Marshal indicated that there is not much to add other than that which had already been dis- cussed, Ed Morris discussed the interim and long term agreements.He asked the participants to explain it once to the board and get their approval.Mike Massin asked if interim agreement is self destruc- tive when the Intertie is available for full capacity.It was noted that ML&P took the agreement to the board and got it ap- proved. Afzal Khan then discussed the remaining start-up/testing plan. The Operating Committee budget was discussed and the committee decided to discuss it further in the next meeting with the previous budget on hand. Harry Beck from the University of Alaska-Fairbanks discussed the interim report titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System".The report isattached.Bob Orr requested Harry Beck to change the wording regarding references to Gilbert/Commonweath. Turning to formal actions of the Operating Committee,Chairman Mike Massin recommended that the Intertie Operating Committee send a letter to Dr.Aspnes,Head,Department of Electrical Engineering, University of Alaska,Fairbanks,expressing the Operating Commit- tee's appreciation for the fine job done on the two Dispatcher Training seminars which took place recently. Chairman Mike Massin then directed the SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE TO MEET ON TUESDAY,JULY 9,1985 AT 9:00 A.M.AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION 9894/410 AFIOC Minutes June 12,1985 Page 4 TRAINING ROOM for the purpose of reviewing the current status oftheAnchorage-Fairbanks Intertie Data Link and particularly in the area of vendors,software and operation,and furnish the full Operating Committee with a written report on the meeting. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM- MITTEE TO MEET ON TUESDAY JULY 9,1985 AT 1:00 P.M.AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION TRAINING ROOM to firm up on schedules, accounting formats,and procedure for transfer of energy on the interconnected utility systems. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE-FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,JULY 10,1985 at 9:00 A.M.IN ROOM 118,DUCKERING BUILDING,DEPARTMENT OF ELECTRICAL ENGINEERING,UNIVERSITY OF ALASKA,FAIRBANKS,ALASKA. Alan Martin motioned for the meeting to adjourn.Bob Orr seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 12:30 p.m. Respectively submitted, H.hh Afzal H.Khan -Secretary Anchorage-Fairbanks Intertie Operating Committee Attachments: 1 July meeting Agenda. 2 Mike Massin's letter to Mike Kelly-Chairman,Alaska System Coordinating Council.3.University of Alaska-Fairbanks letter to Golden Valley Electric Association.Reference:work shop summary. 4 Under Frequency Load Shedding Plan. 5 Letter from John Aspnes to Mike Massin regarding Dynamic Stability Study of the Anchorage-Fairbanks Interconnected Power System. 6.Mike Massin's letter to Dr.John Aspnes,Head,Department of Electrical Engineering,University of Alaska-Fairbanks. AHK/cdc 9894/410 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE -AGENDA- WEDNESDAY,JUNE 12,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports .SCADA/Metering/Communications Subcommittee Dispatcher/Training Subcommittee Dispatch/Scheduling Subcommittee .Utilities Load Shedding Plan. Intertie Status Update (A.P.A.)MmMoOOwWy°eIV.Visitor comments related to items on agenda V.Old Business VI.New Business Recess and work session SCADA/Metering/Communications Dispatcher/Training Dispatch/Scheduling Reserves/Loadshed Interim Agreement Intertie Startup/Testing =@ma)mooOwo>e°eCommittee Budget I.Other VII.Formal Operating Committee action/recommendation VII.Subcommittee assignments IX Adjournment Adjourn by 3:30 p.m. Meeting location:Chugach Electric Association5601Minnesota(Operations Training Room) Anchorage,Alaska(907)563-7494 a212/222 AWA)whe Anchorage Fairbanks intertie- Operating Committee June 7,1985 Mr.Mike Kelly Chairman Alaska System Coordinating Council c/o Golden Valley Electric Association Box 1249 . Fairbanks,AK 99701 Reference:A.S.C.C.Subcommittees Dear Mr.Kelly: At the May 15,1985 montly meeting of the Anchorage/Fairbanks Intertie Operating Committee,a discussion took place on the appropriateness of combining the efforts of the respective .A.S.C.C.Subcommittees with their counterpart Anchorage/Fairbanks Intertie Operating Committee Subcommittees.This was prompted,in part,by a letter from Mr.Larry Wolfe,Chairman of the A.S.C.C. Mutual Aid Subcommittee. It was the conclusion of the Operating Committee that the two groups have different areas of responsibility and that it might detract from the duties of the Operating Committee to combine the two groups'efforts.Therefore,the Operating Committee has taken a position that the two groups should not combine their efforts, but that the Operating Committee should coordinate with A.S.C.C., through the exchange of minutes,and futhermore that the Operating Committee 'Chairman should be involved in the A.S.C.C.Managers' meetings to the extent that it is appropriate. The Operating Committee supports the efforts of A.S.C.C.and will make itself available for assistance when appropriate. Sincerely, WtMlfomMikeMassin Chairman Anchorage/Fairbanks Intertie Operating Committee MEM/csn cc:Bob Orr,Vice Chairman A.H.Khan,Secretary School of Engineering Dept.of Electrical Engineering UNIVERSITYOF ALASKA,FAIRBANKS Fairbanks,Alaska 99701 10 June 1985 Mr.Marvin Riddle Golden Valley Electric Association P.O.Box 1249 Fairbanks,AK 99707 RE:Workshop Summary Dear Mr.Riddle: Week 1 (May 13 through May 17 1985) Topics and examinations were the same as last year.The students werefirst-rate,with excellent attitudes and questions.Verbal course evaluations indicated that the course was well received.Those attending appeared to feel they had gotten a lot of good from the course. The same written two-part exam was used for both entrance and exit testing,as last year.Average results for the nine attendees are tabulated below. Entr viz Exit Quiz Power Fundamentals Power Fundamentals (18 maximum)(19 maximum)(18 maximum)(19 maximum) 10.3 7.3 16.6 17.6 Percent improvement:8.6 = 3 =61%(Power) isi =141%(Fundamentals) GVEA scores follow. Entry Quiz Exit Quiz Power Fundamentals Power Fundamentals (18 maximum)(I maximum)(18 maximum)(19 maximum) D.K.Dunham 14 11 17 17 Pat Green 10 17 18 19 Tom Ramsey 11 7 17 17 UNIVERSITY OF ALASKA 10 June 1985 Page 2 Exit exams and certificates of completion are attached.Pat Green received his certificate last Friday. Week 2 (June 3 through June 7,1985) No entrance/exit exams were given.Again,those attending the advanced course were excellent,presented good questions and appeared enthusiastic about the program. The attached program outline,written prior to the course,was modified. Ken Bradley presented material during two afternoons rather than 3.5 half-days as originally scheduled.John Aspnes presented 4 half-days, Bob Merritt did 3 half-days and Henri Dale did the Friday morning SCADAdemoatGVEA.Bob added material on digital systemsto thecommunicationssection. Many highly favorable comments were made about Henri Dale's presentation.We really appreciate his efforts and the use of the GVEA dispatcher facility for the Friday morning session. Copies of all written opinions about the advanced program are enclosed. If more information is desired,please let me know.Both Bob and I thank you for your interest in and support of these dispatcher workshops.We are both enthusiastic about the student interest shownandenjoyedparticipatinginthisworthwhileprogram. Sincerely, hy (laprea- ohn D0.Aspnes Robert Merritt Professor Professor JDA:RM:061085 Attachments ; ELECTRIC POWER DISPATCHER WORKSHOP June 3 -June 7,1985 at the University of Alaska-Fairbanks ADVANCED COURSE OUTLINE lptePrime Movers .R.P.Merritt a)Gas turbines b)Combined cyclec)Steam d)Hydroe)Diesel PM Economic Operation Ken Bradley a)System load ) b)Unit commitment c)Economic dispatch I Day2 AM Rotating Machines R.P.Merritt a)DC excitation b)Brushless exciters c)Synchronous generatorsd)Real and reactive power generation PM Economic Operation Ken Bradley a)Economic dispatch -IIb)System frequency control c)Interchange pricing Day3 AM System Protectiom John Aspnes a)Circuit breakers b)Instrument transformers c)Relays 1)magnitude2)directional 3)ratio 4)differential 5)pilotd)Transmission line protectione)Differential protectionf)Underfrequency relays Economic Operation Ken Bradley a)Interchange pricing continuedb)Automatic generation control Day4 AM Stability John Aspnes Transmission line equivalent circuits Power flow through a transmission line The stability problem Steady-state stability Transient stability Swing equation Equal-area criterion Solving the swing equation Underfrequency load sheddingyonAvoandnawnaiieaSetNetNeteetStee!P Scheduling Hydraulic Plants Ken Bradley a)Hydro-thermal coordination program PM (Continued Load-flow solutions and control John Aspnes Data requirements Gauss-Seidel and Newton-Raphson methods of solution Information contained in load-flow solution Control of real and reactive power flow and system voltages1)Generator controls 2)Capacitor and reactor banks 3)Load tap changing transformers 4)Static var systemsanoeaeeeeeeee Day3 AM Supervisory Control and Data Acquisition Henri Dale Systems (SCADA) a)Power flow b)Transactions c)Transaction evaluation d)Data acquisition e)SCADA hardware f)Automatic load shed g)Spinning reserve SCADA/Communications -R.P.Merritt ELECTRIC POWER DISPATCHER WORKSHOP ------------------ We would like your opinions on the workshop just completed. J ono RE ' Subjects covered in about the right technical depth and proper amount of time allocated:at Ames Arend tock ten +"ho bare a nt topteteth On malh aeac, Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Lovwaae wr Baa an |aqrpropt bere KymTu Anarveeanton/portvinn n Te nenigu de Subjects you would rather have seen covered more adequately: Overall opinion of this course:/ ,. ;4 fw M_¥Y4q pA TOVorviet)tn Pron Loans ,abr beat _;vy C Tin che,yreertes ZO b mam git Pema ight gWorth:ble ELECTRIC POWER DISPATCHER WORKSHOP EEE We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and proper amount of time allocated: -/LEAL2 THAT THE BACK GROONO WAS NED 7 Wow sTAKO WSMAZHING ¢THE SYSTEM BUT 4RTS OFF sux70 4ecTRRe wee Joo TECAIMAL. Kok THIS BRb0P.ffl FusT 6UESINK BLT 10 SAYS OneyYApott0-324 OF 4s flqwe HAD MIEMER AATKSPATICS|Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Subjects you would rather have seen covered more adequately: CLONEOWC wSRaTCH . Overall opinion of this course: ELECTRIC POWER DISPATCHER WORKSHOP We would like your opinions on the workshop just completed. VERY Cood PresenTaraws:would 2 khii Ta SeaQL:TF/e@ mere ACTIAL deri Pl of dys j297ch PreblensNiepeddLeadProKkurlTe.Subjects covered in about the right technical depth and properamountoftimeallocated: Ves Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Non& Subjects you would rather have seen covered more adequately: SHold TRY To Cover pore 0 Sed afer ari, ALSa cfAss Rosy prroglims Of 4A [OKI As PATE her SHovld be av lA™UP?€déscus sed. Overall opinion of this course: Jevy well Pyuved oT2 Dad Garces ELECTRIC POWER DISPATCHER WORKSHOP We would like your opinions on the workshop just completed. " Geea7- Subjects covered in about the right technical depth.and properamountoftimeallocated: oe PRIDE MOCCAS-JYOUSRNOAS eFC.-svs Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Subjects you would rather have seen covered more adequately: COMMUNICATIONS SECS 4166 A WEEK COVEYO CHTILY BE SAENZ ON AWACOG,GIT AL om AICKHO WAVE --[|ARE ow Lond SLOW ESreAULY OM Ain Ci.TROL 10 FEA, Overall opinion of this course: peat CoD --ZL swt.MINK "yoKE TTAE Siteul)ge NNALLOEOBhcoeCRF6YSR/107°7CS |- ELECTRIC POWER DISPATCHER WORKSHOP ---------- We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and properamountoftimeallocated: wa LE bihicct Vl wee Yoo mek on Lepithe Yl ote,Dh dein Nath ntl.¢salle 2 Ve tah Mons a x LugoprerswleheltiogLlh.Ae |7hLrlex<.tt Niet ensues ae Se $E0!AYUCES FT Abt,ew.ald,y%'iad Cellars 20Subjectscoveredthatdidnotpresentusefulrelevantmaterial| or were allocated too much time for the value received:Clon Sih "Goto 7awh.LAIR LTPAE elon he or Tt tofee.,:' ..foo Oe iJ t e 2 eea pm aot LZ aed L oa aonAeaawaako'Cro.3 a VArans rae ote (fo Loe o:eae VadLit@aycteaVer(Li 6 246K Luis "ol chebrle deSubjectsyouwouldratherhaveseenveredmoreacequarent::/2shee2]List Ld!)36)ae J et lanta oeon Seewet.tote 2 wg,Hon _Jao °eA iP OA 2 net yf Darton?iW:°e. .-a °{te id .LopMitevd Myne eer Lie hl Lei py *-oe.a e.Yewen 5aLreoselvyLe-Kel oy yp $f Ce Pom ee "ve Lh,coo a _.Overall opinion of this.cour ZLehn€tfc.4 feetLLLyA . ;. °ut Atal!etn Dene wt e V's C7.LE,hixe ¥=he = Ded yee o i ..:aa a ,y?..cobeoafAene-Lr 0%SA / a?Le fhe a 2"4c Leb.é Ye ape 3.A SEES Yo oe aT Gl cute DG Dy ws?ja -t ELECTRIC POWER DISPATCHER WORKSHOP ------__---_-_---_--__==_= We would like your opinions on the workshop just completed. Liver Thbi laser yhlrin ,Sur c7 ce ws wee ow mMAtlTow MEESS Omar THe ASTER nary Subjects covered in about the right technical depth and proper amount of time allocated: Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Subjects you would rather have seen covered more adequately: Overall opinion of this course: ELECTRIC POWER DISPATCHER WORKSHOP ------_-_Eo EE]EE _ SS= We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and proper amount of time allocated:Possth le /to re pratical TAilng S S404 4S Gol cle»Volley Presentgiion TheS Marr ay Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Mats LWW4S Over my head Gurr aber Subjects you would rather have seen covered more adequately: 7 Overall opinion of this course: Good Tenjoryedl aud Learned &good L. Tars week.Ples ZF haw The Book+ hend Guts 45 well &S Noles fer (eferance ELECTRIC POWER DISPATCHER WORKSHOP We would like your opinions on the workshop just completed.weg good Subjects covered in about the right technical depth and properamountoftimeallocated:gee Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Subjects you would rather have seen covered more adequately: ZL Lapel Pe)ae aeGe Overall opinion of this course:E.perped)2h LL cmeel og Doe oh haLe,LOhupstih,omnB ELECTRIC POWER DISPATCHER WORKSHOP ee-----------_-i--oI i Ii We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and properamountoftimeallocated: Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Subjects you would rather have seen covered more adequately: Overall opinion of this course:Lau Xd ke Se QUiyonOnSimLele.Mropsat tea\the prratuiadCua&of OmoeL dius patele. ELECTRIC POWER DISPATCHER WORKSHOP ---_-------__-- -oI>IIIII I I IICoC)y)o" y>> We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and proper amount of time allocated:Joo OceP for average Dstarcherfoperarer Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Qjl Subseers were Good burt tip yechevtl Or meg Subjects you would rather have seen covered more adequately: Dey To Day Ty (6 Of martrial for fir Pareners Overall opinion of this course: tive Covrs 4s,however,to dee?fr pverar! Distoreyert/operasors. Wish rf.Aadl aw”ff,-s ad aa a7 mm fe ELECTRIC POWER DISPATCHER WORKSHOP ------ECEOoCU"L___EEeEeEx->-I ---------LL--____i ET, We would like your opinions on the workshop just-completed.Past a Qenibe wih Parve yothe»Oytynn,WHA Wes Aved "WaswrreKwNeeaSoukVnardPagvemoarValvablyyoWeGitvstdays TH Com Subjects covered in about the right technical depth and properamountoftimeallocated:Some WEA Wary O'R my head Lor o€hss TkvIw CarjouGaivvd'pry Ge AQT Pag Oe 7 Subjects covered that did not present useful relevant material or were allocated too much time for the value received:=Ns yy.Fre (By Cad Rasy "Tes a L doatb Rosny \ety >C1».+,heve conacavd L270 Weetirty Eyoieuedee OF The wow eag:ares Subjects you would rather have seen covered more adequately: Tan STS BIA Paackias 06 qvrn OPRAT Pas moths” - . <€@ Cos 5 N rh &Q>( .KW 4 Vans Ar Xv *Vem es Art vA.AYAess R GBroviad bh Gratin uv® ELECTRIC POWER DISPATCHER WORKSHOP We would like your opinions on the workshop just completed. Subjects covered in about the right technical depth and properamountoftimeallocated: Prime Movers Laoad--flow sulatvons dcont ralRotat(ag Mach snes Supervisory Con tro lt Data AcgagteSystem1,Oe tion >ta b 'IB ty Subjects covered that did not present useful relevant material or were allocated too much time for the value received: Few to many eguations for the time Subjects you would rather have seen covered more adequately: Actaal numbers oF values wwe will be working wits, Overall opinion of this course:will do me 2a let af goed (FI domy honeweh Entry Quiz:Electric Power Nispatcher Training Workshop Ll. QVEr vane LK Our hatn \ -) Heat rate is found by dividing thermal energy input to a power plant by mtelectricalenergyoutput(Btu/kWH).An ideal plant with no losses has [é a heat rate of 3412 Btu/kWH.What ts the efficiency of a power plant with a 10,500 Beu/kWH heat rate?3Z.5 So Multiple choice: 2. 3. 4, 12. 13. A synchronous generator has ((nc,)AC)current flowing in the rotor winding,/Operating rotor speeds of steam turbine-driven generators ste Giahery>*lower)than hydro units, The outputs of two synchronous generators each have a frequency of 60 Hz (eyeles/second).Generator 1 is a 4-pole machine which has a rotor speed of 1800 rpm.Generator 2 is a 20-pole machine.The rotor speed ofGenerator2is(60,240,(560,)600,1800,3600)rpm. - Synchronous generator output voltage is controlled by rotor current. false)wa It is not possible for a synchronous generator to,apdifferent tines, supply and absorb reactive power or VARS,(true," Synchronous generator real and reactive power output may be Limited b "(voltage level,field heating,armature (stator)heating,Call of thesenoneofthese).; A generator prime mover throttle setting which controls input mechanical power has a direct effect on (generator rotor current generator rotor )Cangtey)both of these,none of these), ” Tt ts not possible for two generators operating at different rotor (mechanical)speeds to be synchronized (true,Gatse).aAcircuitbreakerismorelikelytointerrupt(overcurrent)overvoltage)."What is the typical interrupting time of a circuit breaker in cycles?3 a Vo / (1 cycle is equivalent to 1/60 second or 16.67 milliseconds); 100 Amperes,(true,A 100 Ampere circuit breaker will be able to interrupt a maximum ofGaise) What does coordination of overcurrent devices (circuit breakers,fuses)mean? Sot Them AO SO They trig Aes ce only?ee:the QV ok Ho!Bulk ana got.healthy”parts of the sysTen Name;Nanhm Entry Quiz:Electric Power Dispatcher Training Workshop 14, 15. 16. An inverse-time overcurrent relay characteristic 1s shown.The hortzont riable is )current)”and the vertical variable is(time,&VeericarVaziABeHogizowraL VARIABLE Given the two buses S and R separated by a reactance X,power (P) transferred between S and R is: Ve VoP==Aim S watts where Vs =bus S voltage,and Ve=bus R voltage $-angle difference between Vs and Vp sin &=sine of the angle 3 (a)If Vo and V,are both changed =3008 volts.to 500,000 volts,how much does P increase?Mos (bd)What is the maximum possible value of S allowed for steady-statestability?90° What must be true of the incremental costs of operating two generating units In a single power plant if the cost of operating both units,is thesmallestpossible?yeprenente /casts are SZ wall - :|IK Dunk germ | Secrio/L mau IX A1.O.OOO/Awmpernes CAN BE WRITER ASs [i ,ea,pa 4CC[x10°A. C}]micet AmPERE. L fA I x10."Ameenes. oO [oO MICRO AMPERES, 2.IF 3.0 AMPERES FLOW THRUA RESISTOR OF g¢ackems,HAT weraBETHEVOCTAGEDROPACROSSTHEREStsTOR+ |12.0 Voers. C)\12x10”Voers, LJ 133.33 Vocrs. "bX {.2 nIO Voers. 3.A COMOUE 7a sven As COPPER HAS APPROKIVIATELY HowPYMANYFREEELECTRONSPERCUBICCenTImeTEResS?! Cc)SG.oBxIO a 1.6 x10>> 23\xl 2.3 X10 Cl Z.0n10'° 4,LN MAGNETIC UNITS WHAT ISA TESLA,A UNITOF: C\INOUCTANCE O1 --mMé6weric FLUX DENSITY 'MAGNETIC FoRcEe /-a ee Pee -.-_.#20 ft owen)Ue 2. 33830SHEET28242.389revesc.foalnananas5.4 6.0 UF cAMCITOR 15 PLACED 1)SERIES WITHA (2 LF cAAaciTOR,WHAT 13 THE EQUWALENT CiReorr AMeraset oO -18 ar Le a 4.0 UF Cl 4.0mF Cl G.omF . 16.(F THE CURRENT LEADS THE VoeTHoE BY 30 Wuar Ls THE POWER FACTOR& Cl 1.732 oO 0.577 a 0.866 |Cc]0.500 7,1F (20.0VocTs (3 APAIED 7A ciRewT ANO 18 AMPRE OF CURRENT Flows BUT TFHE (owER FRCTR !s 0.foWHAT18THE|fowER CONSUMED (NV WATTS? ,-S64,0 WAITS. C)2,160.0 WATTS. q 648.0 WATTS. Ci |800.0 WATTS. - 8.TRON coke tw _TRAVSFORMERS ARE LAmINATEO,70 REDUCE ;7 (]aYsrerexs. ->9 evov ce34xcenrs. (]Fuux DEeNsit?' Cl saruearion. || L |wAnianas9,THE /20.0VeLTrT OvTLerT WNW OVR ZABORATORY /8 MERSURING WHAT Vawe of THE sinE&WAVE,' LC]Peanx (awe 4 Aversee VAWE S cyccepeven CrceaAversgeVAwe LA &me Rms (HEATING vawe ) 1/0.IN A 60 HERTS(EPs)CiReevz-A oma 1 *§(NM00aTOR .HAS AN LNOVCTIVE RERCTANCE CE. Cl O.Go OHMS [|6.0 oHms IL A TRANSFORMER TAS Zea0 TURNS (VV THE PRIMARY 4D00TURNS¢h)THE SECONDARY WINOIKG,1/*2400 VoersAREACROSSTHEPRIMARYWHAT15SETOUOARYVOETHEE? (|320 veers O [200 Vours LM 240 Yers O 297 veers 12,(V/VRAR 60 HERTZ clRcerr 100 AF CAMCITOR "AsACAPACITIVEREACTANCEOF:"Rl 166-6 onms-.g 26.5 °ovms,"r 377.0 Olms Cl 12.6 onms 13./F 12.0 OMS RESIsTHUCE 6S t4)SERIES WITH Sr0 08m OF (NOVETIVE REACTAVCE,WHAT IS THE ciReerrWWNOEDANCE7 C]2.4 Onm Ss, a XM 17.0 ofms -=O 13.0 Otms C]7.0 OHMS. fee)a fel START -STvVP sTATIOW ®a?oe fal'HIGH VOLTAGE CRevIT BREAKER ©-a elo -[Ia]Ww PPER emir switTcH dd)S2 Bl:HORN GAP AIR swiren, IS.WHAT KING OF TRIPPING DEVICE WOLD Go:Nn THE NEVTAAL CERO FkROM A 3d Wye TReuSFeRMER SROKT C]YVNOER VOLTHRE REIAY C)OVER FREQVEUCY RELAY lo ame over cureaur Rew? C]: PoweR DirntenoMl Rev lb.Waar wit,BE 7HE DRIR-RITE ())THE ALASKA SCADRsssjTemFORTHE(VTERTIG? C]300 BAup CI Z24oa ' Ol 480 Ro 9600 ° 4 THOANTRAL.... «z Qvé may a Musare: fee_ALASKA.For ___S00SHREDDING__JON _UNDER FR wey._LeAD cE... wat Nee303 en eefo. _ a 2 tee _. _. a _ Lo HO | ; ; i ; : | ne - 7 _ io er 1 . ; .| __. 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OpSt chopeiis Zt arnood nee {- r T a : oO | A ois Boon dep: aan | gs a); 3 TENS i , NY,y4 : ™: : : CASSe, : a Mer QgeE Tf. | Nag Se: es ksee |Si : tot . |nn ¢ i|aih rhg Tao| aSyy (SSS! let YaSet [is: Saw $vaz een ee|6&5tala; H=53iu 'a sequaied qq iH SBSeG||NW deet| Soquel zy Wafo SBeda GA geduy | OQ SF =r (10. A Qo tatu @' . : ' ' : 1 ih -¢ . . . . oe : + ee ' va| " al + | GS wascm sone commen «015 ONSEN -- mewa -_7 e7Tne7moe,ow=eees= 2 SF FT FS RR RM RN re ON Mm Om -- ma. Pre =2wweae eM & eee ersm= eee ree Saeernseeneeaneze srep]UTiuity 2. ..JEREQ [TiME |.LOAD [Loan |PERcenT PeRceny]|ICoMULAT IVE.circuitfo |(Hz ELAY ISHED [REMAIN |[SHED-[REMAIN LOAD.ISHED ._SUBSTATION(S)CLE 1 ).5 |céea/rinieZ._,.|88.2.iairport-Woodbead Pk peitoct_10 1130/oe 7 ee OEmeghere-Tudor jo pore Ped.aan add HEA ee ©i .'SYSTEM _Po,JO7-7.|226.4 woeewMmUmewreereeaa ICEA-AmeeP Inmeere|57.7 4/991 [|fbuISKatPhamt2GPe:Pdeldoet bbn =|i||{'fs4igaona4co|2 we eeeee ee flots.la }.-4-ab a -Lees 4A.4-4}te.aL.i 'gu CEA-MEA S77 PIS.)fat.|ALP Pda ; " 15 ¢elam _:oe oe |']\ : _Jo !'8 i ce ee PE Pt.cl Po Ep dy de PAL pe |" u .CEA -HEA ..en ots '7.30 .ade:a bepe be,ne |Ala.tea te a ;He a :i !|i |” we Quartz Creek...wpe bbe fed PREP Pet p:Ly _yy ree eee Oe i ee ne ||Lod."mod OCB S26...Pet py bo Pepe fn PUL Pa Pp po Pb pe pt.apie 'hod dps ” :pet .tb.faa i yt '4 i i |2 u ..1.nae 0 4,eee ee eee yet 1 r ;TG |yy |ii:aoe.-ee -|_on aes ees Hid 4 ee Jee mt:a4 - ;S]-22 _--{i.1 of te i ;: .riycedePi Veet|eeeede.fo.i..be\.;=titro-oktad{i\i||ii|iI\i|rti:iapebamit4ia5+|iw]s1:4 - 'en |eens :1 me A ar ees Cae oe eee=G wanon songs Comeany =O 701N OnE EN 2e3 MANE NU ea QR sy,a eal yiie : Anchu.ege'Fairbanks wttertie Uperating Committee RECEIVED JUN 1 8 1985 ALASKA POWER AUTHORITY June 13,1985 John Aspnes,Head Department of Electrical Engineering 233 Duckering Building University of Alaska-Fairbanks Fairbanks,AK 99701 Dear Dr.Aspnes: On behalf of the Anchorage/Fairbanks Intertie Operating Committee, I'd like to take this opportunity to thank both you and Bob Merritt for the fine job done on the two Dispatcher Training semi- nars which took place recently.Comments from the Committee par- ticipants indicated the program was "excellent".The Committeewouldalsoliketoexpressourappreciationforyoureffortsand ability to put the program together on short notice. Sincerely, ike Massin ChairmanAnchorage/Fairbanks Intertie Operating Committee MEM/csn- ccs °° RECEIVED JUN 41985 ML&P/ENGINEERING UNIVERSITY OF ALASKA-FAIRBANKS Fairbanks,Alaska 99701 May 30,1985 Mr.Mike Massin Anchorage Municipal Light &Power Department of Engineering 1200 First Avenue Anchorage,Alaska 99501 Dear Mr.Massin: Enclosed is an interim report for the project titled "Dynamic Stability Study of the Anchorage-Fairbanks Interconnected PowerSystem." The project proposal indicated an anticipated completion date of 31 July 1985.Because unforeseen delays may arise in production of the final report,we request an extension of the project completion date to 15 September 1985. Barring any objection from the operating committee,we will proceed with the September 15 completion date. Sincerely, Qatin Lepr John Aspnes,Head Department of Electrical Engineering 233 Duckering Building [ETT tome enUniversityofAlaska-Fairbanks a |NPUT TINFO/| Fairbanks,Alaska 99701 poe oe if (907)474-7137 foie Be Livbonn<n 74 Io wan _i JA:DP:1804 ne yy,|epee | -pt EES 84-29 INTERIM REPORT ae T0 ANCHORAGE MUNICIPAL LIGHT AND POWER CHUGACH ELECTRIC ASSOCIATION,INC. FAIRBANKS MUNICIPAL UTILITIES SYSTEM GOLDEN VALLEY ELECTRIC ASSOCIATION,INC. DYNAMIC STABILITY STUDY OF THE ANCHORAGE-FAIRBANKS INTERCONNECTED POWER SYSTEM by John Aspnes Harry Beck Institute of Water Resources/Engineering Experiment Station University of Alaska-Fairbanks Fairbanks,AK 99701 May 1985 INTRODUCTION A dynamic stability study of the Anchorage-Fairbanks interconnected power system was funded by Anchorage Municipal Light and Power,Chugach Electric Association,Inc.,Fairbanks Municipal Utilities Systems and Golden Valley Electric Association,Inc.,in 1984.The study was to be performed by Electrical Engineering Department personnel at the University of Alaska-Fairbanks (UAF). One utility,Chugach Electric Association,Inc.,required this interim report as a condition for its participation. Project tasks include: Complete review of system database as developed by previous studies and used by utility engineers and their consultants. Five case studies most significantly impacting total system stability as determined in consultation with Anchorage-Fairbanks Intertie Committee. Initial system power flow conditions for all test cases as a check against results from previous studies and as an aid in determining future system operating conditions. On-line computer model of interconnected Anchorage-Fairbanks power system to reside on University of Alaska Computer Network.This statewide system can provide ready access.to the model for additional studies by participating utility engineers throughout Alaska. Technical consultation on all aspects of project relating to system power flow,transient/dynamic stability,reliability and operation. Final report completely documenting system model,results and analyses of test cases and recommendations on system operation. The database provided by Gilbert/Commonwealth was to be used, regardless of accuracy,in the interest of reducing stability study project cost. Complete relay data and recent load data were not made available in the Gilbert/Commonwealth "Alaska Railbelt Interconnected Electric System Data Book."These data are not expected to be available for incorporation in our final report. Nine representative stability cases involving line faults or equipment failures have been chosen for study.These are described on page 9 of this report.The cases were selected as being most likelyto cause system instability..The ability of static var systems (SVS)to enhance stability was also of interest.Thus,four of the cases provide a direct comparison of SVS impact on system response to a specific fault or equipment failure. DATABASE A computer model of the interconnected Anchorage-Fairbanks electric power system has been created.The transmission system data of the interconnected Anchorage-Fairbanks power network used in this model was collected during the period 1980 to 1984 by Gilbert/Commonwealth for the purpose of performing system studies relevant to the construction of the Intertie.The information has been checked for accuracy by Electrical Engineering Department personnel at UAF. This investigation into the accuracy of the database developed by Gilbert/Commonwealth was conducted last year.A significant amount of the data acquired by Gilbert/Commonwealth from previous studies and 'contained in their database were found to be out-of-date and erroneous. The investigation yielded a number of significant differences between the data reported by the utilities and those used by Gilbert/ Commonwealth in their system model. Included in the Appendix of this report are review comment letters to the utilities identifying those discrepancies.These letters were forwarded to Gilbert/Commonwealth for their use in updating the information contained in the system database.A review of Gilbert/ -2- Commonwealth's report to the Alaska Power Authority (APA),"Alaska Railbelt Interconnected Electric System Data Book,"subsequently revealed that none of the information contained in the comment letters was included in that report. The most difficult and time consuming task in performing a system stability study is assembling and verifying the information that forms the system database.Detailed data concerning the generators,exciters, stabilizers,governors,turbines,transmission lines,transformers, shunt devices,substation loading,relaying,load shedding,unit commitment,intertie power exchange agreements and normal utility operating conditions and practices,for example,must be accurately reproduced in the database if meaningful and relevant results are to be expected.. In most cases it is not possible to obtain all data necessary to perform a stability study without special inquiry being made.For example,data taken from manufacturer's bids are limited in scope and these are often the only known data for a machine.Thus it is often necessary for the engineer to estimate or assume the missing information.With respect to this project,most of the generator data required for the stability study were obtained while most of the exciter and governor data were missing or unavailable.In these instances, Gilbert/Commonwealth provided representative data for system modeling and inclusion in their data book. We have repeatedly requested from Gilbert/Commonwealth a copy of the relay data book that they have assembled from information provided them by the Railbelt utilities.This information is required in order for us to complete the database for the interconnected Anchorage- Fairbanks power system.At the meeting of the Intertie Operating Committee on May 15,1985,we finally requested that the Committee require Gilbert/Commonwealth to furnish us with a copy of the relay data book. The database for the interconnected Anchorage-Fairbanks power network is currently stored on a VAX 11-730 at the UAF Engineering Experiment Station.The database is being made consistent with the information presented in Gilbert/Commonwealth's report to the Alaska Power Authority,"Alaska Railbelt Interconnected Electric System Data -3- Book."Once this database modification is complete,it will be transferred to the University of Alaska Computer Network's VAX 11-780. The database will then be made available to those utilities participating in this study.The acquisition,verification,and computer entry of data necessary for this study were easily the most complex and time-consuming processes associated with this project. STATIC VAR SYSTEMS Static var systems (SVS)are installed at three locations along the intertie;the Teeland,'Healy and Gold Hill substations.They provide var generation under heavy tie line loading and absorb excess line charging vars under light loading conditions.Voltage control is provided on a three-phase basis with voltage fluctuations reduced to less than 0.05 per unit. SVS MVAR output is defined as positive (+)for capacitive operation and negative (-)for inductive operation.The SVS ratings for each of the substations are indicated below: TABLE 1 INTERTIE SVS RATINGS Substation KV MVAR Inductive Capacitive Gold Hill 13.8 <5 +33 Healy 13.8 -33 +22 Teeland 13.8 -22 +22 The static var compensating systems installed along the Anchorage-Fairbanks Intertie are being analyzed to determine their effect on system operation.Potential operating problems caused by disturbances to the system are being analyzed using the computer model -4. to determine their effect on the transient/dynamic stability of the system. The individual SVS is modeled as a thyristor controlled reactor (TCR)in parallel with a capacitor of fixed value.The SVS is then connected to the appropriate winding of the SVS transformer.The slope of the SVS control characteristic curve is the change in SVS output reactive power divided by the change in bus voltage.This change in bus voltage (V)is defined as the SVS-controlled bus voltage minus the reference setting or normal operating bus voltage.The slope referred to above is called the control slope (1/R)and,within the linear range of operation,R is on the order of 3-5%. The transfer function of the SVS provided by General Electric Co. (G.E.),the manufacturer of the device,is: -s TG(s)=Y(s)=<d "%s)RU +ST) where Y(s)is the SVS output in per unit (p.u.)vars on the device base, X(s)is the SVS input V in p.u.volts as defined above,Tq and Ty (in seconds)are the SVS time delay and time constant respectively,and R as defined above.The values chosen by G.E.for these variables in their transient analyzer study of the systems were:(1)R =0.05,and (2)zy =0.150 seconds.The time delay,Ty:has a value of 0.002 seconds. The SVS has the capability to change its output susceptance from full capacitive to full inductive within three cycles.Examination of the transfer function,G(s),above shows that the SVS would respond faster to voltage changes on the controlled bus for a time constant value,Th of three cycles (0.048 seconds)as opposed to the value of 0.150 seconds as specified above.For the model of the SVS used in the preliminary case studies,Ty was selected to be equal to 0.048 seconds. The SVS model used in the preliminary case runs was made more responsive to system disturbances in order to determine if deleterious system conditions would develop due to its operation.The SVS model used is identical to that in the Gilbert/Commonwealth case studies in that they both utilize the same transfer function.The transfer function uses a time constant,Th of 150 msec upon recommendation from the device manufacturer.In the UAF studies this time constant was set -5- to 48 msec (three cycles)to observe the effect of improved response time upon system operation.This significant lowering of the time constantwas done for experimental purposes only.Only the equipment manufacturer,G.E.,could assess whether,in fact,this time constant value is physically realizable and operationally desirable. Preliminary results from stability cases found some objectionable aspects of SVS operation.While the SVS acted to promptly restore SVS controlled bus voltages to the normal range of operation following a disturbance,no significant improvement in system transient stability response was noted for the cases studied.In addition,significant hunting among the devices was evident.For all of these stability cases the power flow initial conditions assumed 45 MW export North. A significant weakness of the EPRI stability program is that it has no provision for modeling static var systems.To fail to accurately model the SVS in studies of the Intertie could result in serious errors occurring in the analysis of power system stability response.It was, therefore,necessary to model the SVS separately from the stability program.At each time step,voltages at the SVS-controlled bus were examined to see if they were within the range of normal operating voltage at their respective buses.If not,a var adjustment calculation was made and the shunt susceptance at the SVS controlling bus was changed in the stability program by the inclusion of a system modification card in the control card deck.This control card contains the value of shunt susceptance calculated and the time into the simulation that the adjustment is to be made.The simulation then continues from this point.This process proved to be tedious and very time consuming but was required for the accuracy necessary in determining the system response. It remains to be seen whether the static var systems actually being installed along the Intertie will perform as well as the model used in our preliminary studies.Since the regulator time lag (T,)value of 0.150 seconds as established by the device manufacturer is much larger than that used in the preliminary case studies (0.048 seconds),it is obvious that the response of the actual SVS devices will be slower than that of those studied here.We recommend that the Intertie Operating Committee request from G.E.copies of the stability analysis that -6§- concluded with the determination of 150 msec for the time constant,Ty. and explore whether this value can be stably lowered for improved system performance. In the final stability case studies that UAF will conduct,the time constant,Th will be set to the value recommended by G.E.Those cases are as identified.It is strongly recommended that th Railbelt utilities further investigate the SVS performance relating to system stability improvement after the Intertie is in operation and a sufficient history of reliable service has been established. STUDY The Electric Power Research Institute (EPRI)software being used for our research includes the power flow,stability and plotting programs integrated into the single package necessary to perform this study.-The software was compiled and the cases prepared for this study were processed on a Digital Equipment Corporation (DEC)VAX 11-730 at the University of Alaska Engineering Experiment Station located on the Fairbanks campus.- Disturbances to the system are being analyzed using the computer model to determine their effect on the transient/dynamic stability of the system.To perform a stability study,the following data are needed: 1.A power-flow study of the network detailing the initial conditions present prior to the disturbance. 2.System data describing in detail the generators and their control equipment,protective relaying,load shedding and the load representation. 3.The location and nature of the disturbance,time of switching and system modifications,and the maximum time for which a solution is to be obtained. The power flow cases must represent relevant combinations of generation dispatch,substation demand level and intertie power flow conditions with normal system configurations.The SVS model should provide continuous control to maintain controlled bus voltages.The acquisition,verification,and computer entry of all data necessary for a stability study is the single most important process associated with this work. The EPRI Power Flow program initiates the stability study by providing the steady-state operation point at time zero.The stability program simulates the dynamic response of the power system for a variety of operational disturbances.The principal function of the program is to determine the power system stability for the prescribed disturbance. For power systems,the most common disturbance that is studied is the three phase fault.The behavior observed immediately after a disturbance is applied to the system under study can be characterized by severe machine oscillations that can result in system breakup or loss of synchronism among units.If any generator rotor angle exceeds 360°or if the oscillations in system variables such as bus voltage or generator velocity deviation grow without bound or are sustained indefinitely,the system is considered unstable and the study is terminated. The first step in the stability calculations is to solve for the initial load flow in the system to determine the initial conditions of bus voltages and power flows in the system.The net step is to apply the disturbance and again solve for the power flows under the new circuit conditions.Comparing the results of these steps will give the difference between the driving torque on the rotor and the electrical load torque for each generator.This difference is the net accelerating torque on the machine rotor.Since the rotor inertia is known,the angular change in rotor position for a given time step can be calculated.Calculations are continued until the stability characteristics of the system are determined.The result is a swing curve in which the angular position of each rotor is plotted as a function of time.From the swing curvean indication of the stability of the system can be determined under the conditions imposed. Since the torque or power equations for the synchronous machines are nonlinear,some appropriate step-by-step method of solving nonlinear. -8- equations is used.The stability program solves the power system equations using the Newton-Raphson iterative technique.A suitable time step is selected.The shorter the time interval selected,the more accurate the results and,obviously,the greater the number of calculations that are performed.This necessitates the use of an extremely fast computer system with a large amount of on-line memory to store the results of these calculations.The Digital Equipment Corporation VAX 700 series of computers is ideally suited for the simulation of these large scale electric networks. 'There are two basic types of disturbances that can be applied to a system when analyzing stability are line faults and equipment failures. Nine representative cases from both categories have been preliminarily chosen and examined to determine their impact on the stability of the interconnected power system.These cases are identified below. CASE DESCRIPTION CASE NO.DESCRIPTION l Loss of Healy SVS 2 Fault at Pt.Mackenzie 138 KV -10 cycle clearing -SVS on-line 3 Fault at Pt.Mackenzie 138 KV -10 cycle clearing | 4 Loss of Healy generator -SVS on-line Loss of Healy generator5 6 Intertie open circuit at Teeland 138 KV -SVS on-line 7 Intertie open circuit at Teeland 138 KV 8 Fault on intertie midway between the Douglas and Teeland substations -SVS on-line : 9 Fault on intertie midway between the Douglas and Teeland substations It has been found that those disturbances that are most likely to result in system instability are line faults.Rapid fault clearing is -9- still considered to be the single most important factor in maintaining system stability.Since faults lasting longer than nine cycles are very likely to produce instability,10 cycles was used as the basis for fault clearing times for this study. Unless the Intertie Operating Committee has alternative cases that they would like us to examine,we will repeat our stability studies based upon the cases that we have preliminarily examined.These final case studies will accurately reflect the system one-line diagram as presented in the Gilbert/Commonwealth data book issued this year.The function parameters of the SVS will also be as given in the data book. A great amount of time was spent by the Electrical Engineering Department at UAF debugging the EPRI software and documentation.In addition,considerable time was spent compiling the source code to produce the executable image that we use in our power flow and stability case runs.It is these executable image files that the utilities will use to run their own case studies.A significant weakness of the EPRI code is the lack of an SVS model for simulation.We investigated the possibility of modifying the code ourselves to rectify this conditions. In discussions with industry experts,we were advised not to attempt to modify the code due to the enormous complexity of the task and the magnitude of the time that would be required. We are presently arranging with the EPRI Software Service Center to purchase copies of the EPRI documentation for the power flow,stability and plotting program software for distribution to utilities participating in this project.This documentation consists of EPRI Power Flow Program User Manual and EPRI Transient-midterm Stability Program and Plot Program User Manual.For those utilities requesting copies of these manuals the cost is $25.00 each. -10- February 11,1985 Mr.LL.G.Miller,P.E. Gilbert /Commonweal th 209 E.Washington Avenue Jackson,Michigan 49201 Dear Mr.Millers As requested by the Intertie Operating Committee,we have reviewed the "Alaska Railbelt Interconnected Electric System Data Book"and have furnished our review comments to you.The data book,however ,only contained relay information regarding underfrequency load shedding.No data were listed regarding distance,oaver-voltage,ocut-of-step blocking,remote relaying or - power relays.In addition,no information was listed concerning the relaying employed along the I[ntertie as designed by Gilbert/Commonwealth. We have been requested by the member utilities of the Intertie Operating Committee to build a database for the interconnected Anchorage-Fairbanks power system based upon the data provided to you by the Railbelt utilities.Would you please provide us with any additional information regarding system relaying as identified above not contained in your original data book described above. Thank you. Sincerely,Joh Qeprta- John Aspnes,P.E.,Head Department of Electrical Engineering 233 Duckering Building University of Alaska Fairbanks,Alaska 99701 (907)474-7137 cc3 David Eberle,Alaska Power Authority Bob Orr,Intertie Operating Committee Harry Beck,University of Alaska DP:17 23 August 1984 Dr.F.S.Frabhakara Gilbert/Commonwealth 209 £.Washington Avenue Jackson,Michigan 49201 Dear Dr.Prabhakaras I am glad that we had a chance to talk with one another in Anchorage last week.I have been impressed with the concern for accuracy and adequacy that Gilbert/Commonwealth has E ss displayed in the preparation of their system studies for the " Anchorage-Fairbanks Intertie Project.To that end,we have been | reviewing your work and the material furnished us by the utilities.Once we have completed our review of this information,we will pass our review comments on to you. a"As you requested I have enclosed the review comments that we've previously sent to the utilities following review of the data of their respective systems.I did not indicate any actual data values in this review as I meant only to highlight areas of concern that the utility reviwer should further explore.He would then determine for himself if the errors in the data were of significance. Since you indicated at the August 25,1984 Intertie Operating Committee meeting that Gilbert/Commonwealth would be using the EPRI 745 stability program for your transient etability study,would you please tell me how you will modify the program to allow for the modelling of the static var systems.I am extremely interested in the modelling of these systems and will be interested to see the approach that you've chosen. I look forward to hearing from you and wish you much success with your project. Sincerely, Harry L.Beck,Research Assistant Dept.of Electrical Engineering 233 Duckering Building University of Alaska 'Fairbanks,Alaska 99701 10 Auguste 1984 Mr.John Marshall Chugach Electric Association Department of Exgineering P.O.Box 3518 Anchorage,Alaska 99501 Dear John, I have reviewed the machine,exciter,governor and turbine data as submittedbyCommonwealthAssociatesattheJuly11,1984,meeting of the ReliabilitySubcommitteeoftheIntertieOperaringCommittee.My review comments arenotedbelow. The following machines have impedances that are much larger then that ofrepresentativemachineshavingthesameoperatingcharacteristicsandsachineratings.The impedance(s)are listed after the machine name: ”International#1 and #2 -Id,Xq and XlInternational#3 -Xd Station 1 fl.#2,#3 -Xd,xX'd,Xq and ilBerniceLake#2 -il Beluga #8 -Xd and%q The following machines have impedances that are much smaller than that of representative machines having the same operating characteristics and machine Tatings.The impedance(s)are listed after the machine came: International #3 <-Xq Eklutna #1,#2 Xd and Xl Cooper Lake él,#2 -Xd,x'd,Xa,X'q The following machines are not represented with machine,exciter,governor and/or turbine data:; Bernice lake #1 Bernice Lake #2 Kklutna fl,#2 Station 1:#1,#2 Beluga #8 .Cooper Lake #1,#2 International #1,#2 The following comments apply: a.Armature resistance data is missing for all machines; be Exciter model type |is not an exact representation of EPRI model type EA; c.Time constants TA and TAl used in exciter model type 1 have assigned values that are self-cancelling; d.Exeiter data ia not exact but merely representative making its use questionable as far ag adequacy and accuracy of the final system model is concerned; e.Commutating reactance data for all type 3 exciters ia missing; Review of Data 10 August 1984 Page 2 f.All GE generators in the CZA system ere modelled with GE type SCPT type exciters.These generators were installed ower a 17 year period making the likelihood that they all utilize the same type of exciter with the same response characteristics highly improbable. g-Regulator limits for the exciters used with the hydroturbines appear erronecus;bh.The type 2 steam turbine and governor representation is unnecessarily complex as a number of the function blocks are self-cancelling.It is mot spparent that this is a suitable representation to be using for combustion and hydro type turbines. If you have any questions concerning this review,please contact me at either 474-7137 or 452-2709. Sincerely, Harry L.Beck,Research Assistant Dept.of Electrical Engineering 233 Duckering Building University of Alaska | Fairbanks,Alaska 99701 HB:MG:21/11 30 July 1984 Mr.Sam Matthews Homer Electric Association 3877 Lake Street Homer,Alaska 99603 Dear San, As promised,I have reviewed the line and load data for your system as submitted by Commonwealth Associates at the July 11,1984 meeting of the Reliability Subcommittee of the Intertie Operating Committee.My 'review comments are noted below: The following substations were shown to have winter 1984--'85 demand projections different from those calculated by HEA for the saneperiod: Kenat Fritz Creek Soldotna Bernice 69 kV Homer Kasiloff Anchor Point Bernice 25 kV Tesoro Bernice 4 kV The following transformers and line sections were shown to be incorrectly modelled or to have per unit impedances and/or charging susceptances different from those indicated in the recent HFA sectionalizing study prepared by Miner &Miner. Bernice -Soldotna Soldotna -Kastloff Anchor Point -Diamond Ridge Diamond Ridge -Fritz Creek Soldotna 69 kV -115 kV Diamond Ridge 69 kV -115 kV Bernice 4 kV -24.9 kV -69 kV Bernice -Tesoro Kasiloff -Anchor Point Diamond Ridge -Homer Soldotna -Kenai Would you please provide me with a copy of the review comments that you send to Commonwealth Associates for their aid in the preparation of the Railbelt Electric Utility System Data handbook.Thank you. Sincerely, a .. ,.ee é 2 Harry L.Beck,Research Associate School of Engineering 233 Duckering Building University of Alaska Fairbanks,Alaska 99701 907/474-7137 lo July 1984 Mr.John Marshall Chugach Electric Association Department of Engineering P.O.Box 3518 Anchorage,Alaska 99501 Dear John, As promised,I have reviewed the line and load data for your system as submitted by Commonwealth Associates at the July 11,1984 meeting of the Reliability Sub- committee of the Intertie Operating Committee.My review comments are noted balow: The following substations were shown to have winter '84-85 demand projections difference from those calculated by CEA for the same period: International University Indian Girdwood Daves Creek Portage Beluga Hope Bernice Lake The following transformers and line sections were shown to be incorrectly model- ed or to have per unit impedances and/or charging susceptances different from those indicated on the CEA positive sequence impedance diagram -1984: Beluga?13.8 -Beluga 138 Beluga8 13.8 <-Beluga 138 Beluga 138 -Beluga 230 Bernice3 13.8 -Bernice 69 Bernice 69 =Tesoro 69 Bernice4 13.8 -Bernice 69 Intnl.138 <=Pt Wzfl 138 Intnl.138 -Pt.Wzf2 138 Beluga 230 <=-Pt.Mkz 230 Pt.Mkz 230 <-Pt.Mkzl 138 Teeland 230 -Pt.Mkz 230 Pe.Mkz 230 <-Pt.Mkz2 138 Soldtn.69 =Kenai 69 Qtz.Cr.69 <=-Cpr.Lk 69 Univ.34.5 -115 -138 Univ.230 -Univ 138 Univ.230 -Pt.Mkz 230 Bernice 4.16 <-24.9 =69 Daves 69 -Daves 24.9 Daves 24.9 -Seward 24.9 a.The shunt reactor at &.Terminal 230 is not modelled; b.Rated power for all generators is not correctly specified. Would you please provide me with the winter and summer dispatch schedule for all generators including scheduled power and vars,operating output voltage,droop setting,and if under automatic generation control (AGC).The interchange power flow agreements between CEA and other utilities would also be extremely helpful. I have started to review the machine data for your system.After this review,I will again forward my comments to you.Thank you for your assistance. Sincerely, eeHarryL.Beck,Research Assistant 233 Duckering Building 18 July 1984 Mr.Ken Ritchey Matanuska Electric Association Department of Engineering Palmer,Alaska 99645 Dear Ken, As promised,I have reviewed the line and load data for your system as submitted by Commonwealth Associates at the July 11,1984,meeting of the Reliability Subcommittee of the Intertie Operating Committee.My review comments are noted below: l.The following substations were shown to have winter '84-85 demand projections in excess of 102%abowe those calculated by MEA for the same period: Anderson Settlera Bay O'Neil Reed Site Bay Camp 2.The following substations were shown to have winter '84-85 demand projections in excess of 10Z below those calculated by MEA for the same period:, 'Lucas Shaw Douglas Herning McRae Briggs Pippel Lazelle 3.The following line section were shown to have per unit impedances and/or charging susceptances in excess of 102 above those recorded by MEA: 1822 1825 1826 1830 4.The following line sections were shown to have per wit impedances and/or charging susceptances in excess of 10%below those recorded by MEA: 1801 1802 1804 1807/1808 1821 1823 1824 1830 5.The following line sections were not modelled correctly (e.g. substation located at its tap): 1806 1827 1828 1829 Would you please provide me with the following information/material: a.Impedances of the Pippel,Reed,&Palmer substation transformers b.Impedances between the taps and the transformers for the Pippel, Reed,&Palmer substations c.Winter '8485 projected demand for palmer substation d.Amended one-line diagram (basic)of the Teeland substation after 230 kV conversion with transformer &line impedances shown e.acomplete copy of the review comments you make to Common- wealth. Thank you for your assistance, Ss Harry L.Beck,Research Assistant wnmewn 7.1 eeeOePeeteoNMmanearealONewemeAemeeceegoefoeatsmnidemeeaa0 Electrical Engineering Department UNIVERSITY OF ALASKA.FAIRBANKS Fairbanks,Alaska 99701 RECEIVED27June1984 jul 0 2 1984 Mr.David Eberle KA POWER AUTHORITYAlaskaPowerAuthority.ALAS S324 W.Sth Avenue . Anchorage,Alaska T7501 Dear Mr.Eberle: We are presently tuilding the data base for a dynamic stability study of the Anchorage-Fairbanks interconnected power network.The mast important requirement of providing a highly accurate study is the model representation of the system.System stability depends on characteristics cf all elements af the power system.This includes the response characteristics of the turbogenerators and their control equipment,the dynamic characteristicsof the loads,and the device types and settingsof the protective equipment used. To ensure that our computer model is the most accurate representation of the network to date,we have requested from the Intertie user utilities,data that describe their power systems transmission lines,machinery, control and protective equipment,.load information,and operating guidelines.All Utilities that we contacted experienced no difficulty in providing us with the requested information with.one notable exception.That exception is the generator and contral equipment (e.g. exciter,governor,turbine,stabilizer)response characteristics.In this area,the data that the utilities have provided are lacking.' We are aware of efforts by Commonwealth Associates to acquire this same information from the utilities and from the generator manufacturers.We don*t know,however, how successful they were in cbtaining this data.I would like to have you request that Commonwealth provide us with UNIVERSITY OF ALASKA the data that they used in their stability study including any assumptions that were made in instances where this information was not available. I appreciate your assistance. Sincerely. CLYatty K-GEeck So, John Aspnes,F.E. Dept.of Electrical Engineering 235 Duckering Building University of Alaska Fairbanks.Alaska 99701 907/474-7137 @ OPERATING COUMITTEE MEETIN C. JUNE 12,19S |Ale /YSSL MLL? K ppenc LIRR 279-761 x§ZL CVES Ysa-NTi yw 20% Mpptdssl Limole Evey Yt2-thtl xX 2759 Alan Martyn FMUS He2-2107 Maw el Wes (2023.Q2L-200/ |HARRY _BECK U"AF VY2Y-F137 Kay Lf Dyers CEH 564-0787 San UatHews Ated Kya ZFC-Blo]Shaw Srwer Kewski Arad 745-393 ;Tednn C Marshal)CER SLY -D602 oy A.Kite.Ce dob £f3--307/ Aezae 4 kitAc!APA 276-000 /[ EB.MoRRL AP4 27b-000/ L104 1S @ Gilbert /Commonwealth engineers and consultants GILBERT /COMMONWEALTH INC.OF MICHIGAN,209 E.Washington Avenue,Jackson,MI 49201/Tel.517 788-3000 May 23,1985 RE¢APAL-20597 ,CEiy.,Ep Mr.David R.Eberle Alaska Power Authority 334 West 5th Avenue Anchorage,AK 99501 Dear Mr.Eberle: SUBJECT:ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE PROJECT MEMORANDUM REPORT HARMONICS MEASUREMENTS AT HEALY POWER PLANT Enclosed is our "Memorandum Report -Harmonic Measurements at HealyPowerPlant"for your review and comment.This is the only distribution|which we will make of the report until we receive instructions from you. A similar report for the Teeland substation measurements is in preparation and we expect to mail it within one week. Sincerely, e G.Miller,P.E. ject Manager LGM/ljr Enclosure 525 Lancaster Avenue,Reading,PA/Morgantown Road,Green Hills,Reading,PA 215 775-2600 209 East Washington Avenue,Jackson,MI 517 788-3000 MEMORANDUM REPORT HARMONIC MEASUREMENTS AT HEALY POWER PLANT FOR THE ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE PROJECT Prepared by J.T.Hancock,P.E. Gilbert/Commonwealth Inc.of Michigan May 23,1985 MEMORANDUM REPORT HARMONIC MEASUREMENTS AT HEALY POWER:PLANT Prepared by Gilbert/Commonwealth Inc. SCOPE Harmonic current measurements were made in current transformer secondary circuits for the Healy generator,24.9 kV feeders Rl (Usibelli Coal Mine)and R2 (West River)and the Gold Hill 138 kV transmission line. 'Harmonic voltages were measured in 120 volt potential transformer circuits for the generator bus,24.9 kV bus and 138 kV bus.Measurements were made on April 16,17 and 20,1985 under various operating conditions of harmonic producing equipment at the Usibelli Coal Mine (UCM). CONCLUSIONS 1.The measured Healy generator harmonic currents are less than 1 percent of the fundamental current.The 5th harmonic currents are 0.6 percent or less and 7th harmonic currents are 0.4 percent or less.Based on these observations it can be concluded that for operating conditions similar to those measured:a)the Healy generator has not been exposed to significant harmonic currents and b)that generator harmonic levels vary insignificantly as UCM operating modes change. 2.The relatively consistent harmonic current levels on the West River feeder R2 suggest that harmonic sources exist on the feeder. 3.When the UCM capacitors are disconnected,harmonic currents for the llth and 13th harmonics (7.3 percent and 4.9 percent respectively) are injected into the 24.9 kV power system. 4.Harmonic voltage distortion factors for the 24.9 k¥and generator buses satisfy recommended levels.The harmonic voltage distortion factor for the Gold Hill 138 kV line slightly exceeds recommended levels but this does not necessarily indicate a problem.- JTHancock 5/23/85 Page 1 of 9 RESULTS AND DISCUSSIONS The results of the measurements are summarized in Exhibits 1 and 2 and are expressed as a percent of the 60 Hz fundamental frequency components. For current measurements,all results are referenced to the 60 Hz currents measured during "Normal"conditions.Voltage measurements are referenced to the 60 Hz voltages measured for that load case.The several UCH operating conditions existing during the measurements are described in Exhibit 3. A review of the harmonic currents in Exhibit 1 shows: 1.harmonic currents produced by the UCM peakshaver have a major effect only on the 24.9 kV feeder Rl to UCM. harmonic currents at the generator are small (1 percent or less) and change relatively little for various UCM operating modes.The 5th harmonic current varies between 0.3 percent and 0.6 percent of normal 60 Hz current and the 7th harmonic stays relatively constant at 0.3 percent to 0.4 percent. | Significant increases in 60 Hz currents were noted at all measurement locations when the UCM capacitors were disconnected and normal dragline operations were occurring. With the capacitors disconnected,several notable differences in harmonic levels on the UCN feeder R1 existed: -harmonic 7,0.5 percent compared to 4.8 percent for normal. -harmonic 11,7.3 percent compared to 4.1 percent for normal. -harmonic 13,4.9 percent compared to 0.5 percent for normal. Disconnecting UCM capacitors had no significant effect on harmonic JTevels,above the 3rd harmonic,in the West River feeder R2 and Gold Hil]138 kV line.Slight increases in harmonics 11 and 13 were observed with the capacitors off. JTHancock 05/23/85 Dana 9 nf Q An overall measure of harmonic voltage effects on power system voltage is the voltage distortion factor expressed as a percent of fundamental. The voltage distortion factor is defined [1]as Sum of the squares of all harmonic voltage amplitudes 1/2 x 1002 square of fundamental voltage amplitude Recommended levels for voltage distortion [1]for general power systems are: 2.4 kV -69 kV 53 115 kV and above 1.5% Voltage distortion levels on the generator bus and 24.9 kV bus satisfy the recommended limit.Voltage distortion for the 138 kV bus is 2 percent and slightly exceeds the recommended level.This does not necessarily indicate that a problem exists. Individual harmonic voltage levels for "Normal"operating conditions are generally larger than for other operating modes.Two exceptions occur for the capacitors off case for the llth and 13th harmonic voltages 'on the 24.9 kV bus.These higher levels are a result of llth and 13th harmonic currents injected into the 24.9 kV system from the UCM peakshaver when the capacitors are disconnected. SOURCES OF HARMONIC CURRENTS AND VOLTAGES Any nonlinear circuit element driven by a sinusoidal voltage source will generate harmonic currents.In power systems the most common nonlinear circuit elements are magnetic devices,i.e.,generators,transformers and reactors.However,such devices are designed to operate below magnetic saturation thereby minimizing the nonlinearities and harmonics produced when energized at rated voltages. JTHancock 05/23/85 Page 3 of 9 Solid state switching devices (SCRs and thyristors)used in rectifier/inverter applications are another source of harmonics.At the Usibelli Coal Mine,the peakshaver,is an ac-dc electromechanical system which stores energy in mechanical form during non-peak load times and returns energy to the power system when peak power requirements by the dragline exceed a preset level.This arrangement reduces the peak power the utility is required to supply.The peakshaver rectifier/inverter produces and injects small harmonic currents into the power system. The UCM peakshaver rectifier/inverter is a 12-pulse system.The 11th and 13th harmonics are the lowest frequency harmonics generated by an ideal 12-pulse system.In practical systems low levels of 5th and 7th harmonics may also be present. OPERATING CONDITIONS DURING MEASUREMENTS Exhibit 3 summarizes the operating conditions during the measurements. Measurements made on April 16,1985 were for normal UCM operations. April 17 was a scheduled maintenance day.Reduced dragline loads occurred as the dragline buckets were positioned for repair.Later,all dragline operation was stopped,and both the peakshaver and capacitors at UCM were de-energized.The 24.9 kV-6.9 kV transformer,however,remained energized.On April 20 measurements were made for normal dragline operation but with UCM capacitors de-energized.At about 1230 hours, April 20,UCM completely de energized the dragline,capacitors,peakshaver and the 24.9 kV-6.9 kV transformer:for a short time. MEASUREMENT SYSTEM The measurement system consisted of a Hewlett Packard (HP)spectrum analyzer (HP3580A)and X-Y Recorder (HP7045B).For current measurements a 0.1 ohm resistor was inserted in series with the current transformer (CT)secondary circuit using a Westinghouse test switch.A transformer was used to isolate the measurement equipment from the CT circuit. JTHancock 05/23/85 Page 4 of 9 Exhibit 4a shows the circuit.For voltage measurements a 10:1 resistive voltage divider was used to reduce the potential transformer (PT)secondary voltage (about 120 volts)to less than maximum instrument input voltage. See Exhibit 4b. The HP 3580A spectrum analyzer is equipted with an internal calibrator which allows calibration of the instrument.Calibration was checked periodically. "External components (isolation transformer circuit and voltage divider) were calibrated using the internal signal source (tracking oscillator) in the HP3580A which provides a variable frequency voltage source. The HP7045B X-Y recorder was adjusted to plot graphs equivalent to the display on the spectrum analyzer.The frequency scan time on the HP3580A was adjusted so that the plotter properly reproduced the spectrum display. For most measurements a scan time of 10 seconds per division was used giving an overall scan time of 100 seconds.A few measurements used a scan time of 20 seconds per division. Most measurements were made over the frequency range 0-5 kHz (83rd harmonic)A few measurements were made over the range 0-2 kHz (33rd harmonic).All measurements were made using a spectrum analyzer bandwidth _of 10 Hz.The 10 Hz bandwidth gave adequate frequency discrimination to easily resolve the various harmonics present. REFERENCE 1.IEEE Standard 519-1981,Guide for Harmonic Control and Reactive Compensation of Static Power Converters. JTHancock 05/23/85 Page 5 of 9 EXHIBIT 1 -HARMONIC CURRENTS AT HEALY 60 Hz Harmonic .Generator Fund.3 5 7 9 11 13 (3)(2)(2)(2)(2)(2)(2) Normal 100.0 1.0 0.4 0.3 0.1 0.1 - Reduced 94.4 0.7 0.3 0.3 0.1 0.1 - OCP OFF 94.4 0.7 0.3 0.3 0.1 0.1 - Cap.OFF 112.2 0.9 0.6 8 8§=6.:0.4 0.1 0.1 0.1 UCM 24.9 kV Feeder Rl Normal 100 2.8 2.5 4.8 1.2 4.1 0.5 Reduced 29.9 0.9 0.6 0.3 0.1 0.2 0.1 DCP OFF 28.2 0.6 0.5 0.3 0.2 0.1 0.1 Cap.OFF 112.2 2.0 2.4 0.5 0.3 7.3 4.9 6.9 kV Sub OFF 8.9 0.8 0.6 0.4 0.2 0.2 - West River 24.9 kV Feeder R2 Normal 100 4.6 5.0 3.4 1.2 1.2 0.3 Reduced 112.2 4.9 4.7 2.9 0.9 1.4 0.2 Cap.OFF 125.9 5.5 5.0 3.4 1.3 2.0 0.5 Gold Hill 138 kV Line Norma]100 1.3 0.5 0.4 0.1 0.5 0.3 DCP OFF .100 1.2 0.4 0.3 0.1 0.4 0.2 Cap.OFF 112.2 1.6 0.4 0.4 0.1 1.2 0.5 Note:Measurement conditions are described in Exhibit 3. JTHancock 05/23/85 Page 6 of 9 Generator Bus Normal Reduced DCP OFF Cap.OFF 24.9 kV Bus Normal Reduced DCP OFF Cap.OFF 6.9 kV Sub.OFF 138 kV Bus Normal Reduced DCP OFF Cap.OFF Note:Measurement conditions are described in Exhibit 3. JTHancock 05/23/85 Page 7 of 9 EXHIBIT 2 -HARMONIC VOLTAGES AT HEALY 60 Hz Fund. (2) 100 100 100 100 100 -100 100 100 100 100 100 100 100 Harmonic 3.i 7 9 ll 13 (2)(2)(2)(2)(2)(2) 3.8 1.6 0.6 0.2 0.5 0.1 0.2 0.9 0.3 -0.1 - 0.2 1.1 0.2 -0.1 - Q.1 1.0 0.2 -0.1 - 2.7 2.5 1.0 0.3 0.5 0.1 0.5 1.1 1.1 0.1 0.3 0.1 0.5 1.1 0.5 0.1 0.3 0.1 0.4 1.1 0.4 0.1 1.1 0.3 0.4 1.0 0.5 0.1 0.3 - 1.2 1,5 0.4 0.1 0.3 0.1 0.3 1.3 0.5 -0.2 0.1 0.4 1.6 0.5 -0.1 0.1 0.3 1.4 0.4 -0.3 0.3 Voltage Distortion (2) 4.2 1.0 1.1 1.0 4.0 1.6 1.3 1.8 1.2 2.0 1.5 1.7 1.6 EXHIBIT 3 HARMONIC TEST CONDITIONS UCM 24.9kV Equipment Dragline Peakshaver UCM Capacitors 6.9kV XFMR Condition Normal Normal Digging In Service In Service In Service Reduced Not Digging '.But Moving .Bucket In Service In Service In Service DCP Off Not in Not in Not in Service Service Service In Service Cap.Off Normal Not in Digging In Service Service In Service 6.9 kV Sub Off Not in Not in Not in Not in Service Service Service Service JTHancock 05/23/85 Page 8 of 9 EXHIBIT 4 -MEASUREMENT CIRCUITS 10m 1800.n. > TO SPECTRUMCIRCUIT680.0 >ANALYZER INPUT 0/ ISOLATION TRANSFORMER A)HARMONIC CURRENT MEASUREMENT 44.7Kn. <-o-_WW »TO PT 4 SPECTRUM CIRCUIT Kin >ANALYZER INPUT <-o-oO) 20.5 dB VOLTAGE DIVIDER B)HARMONIC VOLTAGE MEASUREMENT JTHancock 05/23/85 Page 9 of 9 &q Gilbert/Commonwealth engineersandconsultantsGILBERTASSOCIATES,INC.,di/b/a/GILBERT/COMMONWEALTH,INC.;COMMONWEALTH ASSOCIATES,INC., SEATTLE OPERATIONS CENTER,14450 N.E.29th Place,Suite 216,Bellevue,WA 98007/Tel.206 882-3071/Telecopy 206 883-8663 June 4,1985 SOC-85-1113 Mr.Mike Massin Operating Committee Chairman Anchorage Municipal Light &Power 1200 East First Avenue Anchorage,AK 99501 Dear Mr.Massin: Enclosed are the copies of the Operating Procedures for operation of the Alaska Intertie.The appropriate number of copies,as requested by the individual utilities, are being transmitted to the Participants. Please note that an addendum is included in the Operating Procedures which addresses the interim concerns requested by the Operating Committee as follows: 1.Gold Hill Substation transformer out of service 2.Switch No.830 normally open 3.No generation at Eklutna 4.One unit operating at Eklutna 5.Two units operating at Eklutna _ 6.Transmission between Teeland and Point McKenzie out of service 6a.Using the 115 kV line from Eklutna.- The Operating Procedures are based on the operation of the SVS systems as presently described by GE.These Operating Procedures complete the request and authorization of APA as under their directions and guidelines as well as those of the Operating Committee. Should you have questions or require additional explanation,please advise and we will make every effort to provide them in a most timely fashion. Sincerely, D.A.Rice Engineering Dept.Mgr.,SOC Energy Transport Systems DAR/jh Enelosure Principal Offices . P.0.Box 1498,Reading,Pennsylvania 19603/Tel.215 775-2600 /209 East Washington Avenue,Jackson,Michigan 49201/Tel.517 788-3000 G Gilbert /Commonwealth engineers and consultants. SEATTLE OPERATIONS CENTER,14450 N.E.29th Place,Suite 216,Bellevue,WA 98007/Tel.206-882-3071 /Telecopy 206-883-8663 Mr.Mike Massin June 4,1985 Page 2 Similar Letters to:A.Kahn Larry Kolp John Marshall Mike Massin Sam Matthews Bob Orr Ken Ritchie Copies to:Dave Eberle -W/A John Aspnes -W/A Lytle Miller Dr.Prabhakara Dave Shafer @,Gilbert /Commonwealth engineers and consultants GILBERT ASSOCIATES,INC.,di/b/a/GILBERT/COMMONWEALTH,INC.;COMMONWEALTH ASSOCIATES,INC., SEATTLE OPERATIONS CENTER,14450 N.E.29th Place,Suite 216,Bellevue,WA 98007/Tel.206 882-3071 /Telecopy 206 883-8663 dune 4,1985 SOC -85-1112 Mr.Mike Massin Operating Committee Chairman : Anchorage Municipal Light &Power ” 1200 East First Avenue Anchorage,AK 99501 Dear Mr.Massin: Enclosed are copies of the Alaska Intertie Transfer Loss Tables broken down by sections,in increments of load of 10 megawatts and to the nearest 1 megawatt of loss.These tables are developed as per instructions and agreement of theOperatingCommitteeandundertheauthorizationoftheAlaskaPowerAuthority. The Intertie Transfer Loss Tables were developed to provide guidance in determining a reasonable loss estimate to be used in making electrical transfers from one Participant to another.On line system load flows should be used as soon as they are available as they can provide a more realistie basis for determining the loss that would occur on a particular transfer as they will utilize the exact transmission configuration available. Ineluded with the Intertie Transfer Loss Tables is a written discussion of their use and copies of the supporting load flows.We believes this completes the assignment on the Alaska Intertie Loss Transfer Tables but should you have any questions, please advise. Sincerely, D.A.Rice Engineering Dept.Mgr.,SOC Energy Transport Systems DAR/jh Enclosures Similar Letters to:A.Kahn Larry Kolp John Marshall Mike Massin Sam Matthews Bob Orr Ken Ritchie Copies to:Dave Eberle -W/A John Aspnes -W/A Lytle Miller Dr.Prabhakara eoPrincipal OfficesveShaferP.O.Box 1498,reading PAVE,S|afer,215 775-2600 /209 East Washington Avenue,Jackson,Michigan 49201/Tel.517 788-3000 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE MINUTES WEDNESDAY,MAY 15,1985(At Municipal Light and Power,Anchorage) Attendance: James D.Hall John C.Marshall Ray L.Duncan Robert Orr Marvin Riddle Larry Colp Sam Mathews Mike Massin Ken Bradley Harry Beck Dan Rice Ed Morris Afzal H.Khan Howard Thacke Matanuska Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Golden Valley Electric Association Fairbanks Municipal Utilities System Homer Electric Association Anchorage Municipal Light and Power Municipal Light and Power Operation's Consultant University of Alaska-FairbanksGilbert/CommonwealthAlaskaPowerAuthority Alaska Power Authority Alaska Power Authority The meeting was called to order by Chairman Mike Massin at 9:15 a.m.in the Municipal Light and Power main conference room. Bob Orr motioned that the minutes be adopted as written and Mike Massin seconded the motion.The motion was approved unanimously. Sam Mathews then motioned for the agenda to be adopted with modi- fication -VI H A.S.C.C.Bob Orr seconded the motion and it was approved unanimously. Under Committee's correspondence reports,Mike Massin noted that a letter is sent to Mr.Virgil Gillespie in appreciation for theservicesprovidedbyMr.Keith Sworts. Bob Orr gave a report on the meeting held by the SCADA Meter-_-ing/Communications.Subcommittee..This meeting was .held.on.-.-May 14,1985 at the Municipal Light and Power Conference room.(Bob Orr also furnished the Operating Committee with a set ofminuteswhichareattached.) Marvin Riddle gave a report on the meeting by the Dispatch/Training Subcommittee.This meeting was held on April 23,1985 inFairbanks.(Marvin Riddle also furnished the Operating Committee with a set of minutes and a letter from John Aspnes which areattached.) 9614/387 AFIOC Minutes May 15,1985 Page 2 ' Marvin Riddle also provided the Operating Committee with a set ofminutesfromtheDispatchSchedulingSubcommitteemeeting.ThismeetingwasheldonMay14,1985 at 9:00 a.m.at the MunicipalLightandPowerConferenceroom. Mr.Hall joined the meeting at 9:50 a.m. Mike Massin noted that HEA,ML&P,and CEA planned to meet today in the afternoon to work on utility load shedding plan. Afzal Khan,from the Alaska Power Authority was then asked to provide the Operating Committee with a status report on the Anchorage-Fairbanks Intertie construction.Afzal Khan and Dan Rice furnished an Intertie Status update.Afzal Khan reported that according to Westinghouse Goldhill transformer will be ready for shipment in June 1985.The installation and field testing will take place sometime in August 1985.Westinghouse will submit a detailed schedule.As for Healy SVS,the General Electric is scheduled to be in Healy substation on June 3,1985.Also,GeneralElectricwillsendafieldengineertodosomeworkonTeelandSVS on May 27,1985.He also noted that a report on Harmonic measure-ments (Healy substation)is due from Gilbert/Commonwealth.SVS bus modification will take place at Goldhill SVS and Healy SVS once wedetermineHealySVSstart-up procedure.Dan Rice then discussed indetailthedevelopmentoflosstableandhehandedoutalistofassumptionsandloadflowcaseindex.Three (3)more cases are'added to a list of sixty-one (61)cases.As for interim capabilityoftheIntertie,Dan Rice noted that this will be addressed in the Operating Procedure Manual.The Operating Procedure Manual will beavailablefordistributionwithintwoweeks.Bob Orr brought to the attention of Afzal Khan and Dan Rice,that there is no PT on the Douglas line to give voltage reading for the synchronizing purposes at Healy substation.Afzal Khan said that he will look into this PT location. There were no visitor comments;however,Mr.Harry Beck from the University of Alaska Fairbanks did sit in as a visitor. <The Operating Committee had no old business to conduct at the meeting. _Turning to.New.Business,the.Operating Committee recessed into.aworksessionat11:00 a.m.; Turning to SCADA/Metering/Communication,Bob Orr discussed the contents of minutes of Subcommittee meeting which was held on May 14,1985.He further briefly discussed the problems associated with Healy SVS and Bubble memory recorder.He asked Alaska Power Authority to locate Bubble memory recorder translator,if there are a any.Mr.Hall offered his services to translate by providing acoehardcopyorafloppydiskette. 9614/387 @AFIOC Minutes May 15,1985 Page 3 \ \ Marvin Riddle indicated that he does not have anything more to add other than that the minutes of Dispatch/Training Subcommittee meeting,which he provided. Turning to Dispatch/Scheduling,Mike Massin felt that subcommittee need to sit down and really get into developing a full blown schedule.He noted that the intertie will be in full operation in August 1985.Hank Nikkels indicated that there is an outlineavailable.Mike Massin asked ML&P and CEA (each requested Subcom- mittee to come up with schedules,accounting formats,purchase ofpowerandlinelosstables.The committee discussed a mid point of the Intertie and it was noted that the regulating point is at the Douglas substation.Marvin Riddle pointed out that hourly sched- ules have already been designed but the mid point has not beenaddressed.Further discussion was centered on accounts,schedules, and complete transactions at various places and line losses.Mike Massin suggested that after this meeting Marvin Riddle,Ken Bradley,Hank Nikkels,and Ray Duncan should meet to come up withrecommendations.Ray Duncan asked that he be excused,but will go along with their recommendations. Bob Orr asked Northern and Southern group to look at the loadsheddingplan.John Marshall,Sam Mathews,Jim Hall and Bob Orr planned to meet after this meeting. Ed Morris,from the Alaska Power Authority,discussed the various aspects of the intrim and long term Agreement.Bob Orr asked ifthereareanysignificantchanges.Ed Morris replied that somelanguageischanged.He informed the Committee that by next week the Intertie Agreement will be with the Managers.The ManagershavenotyetseentheInterimAgreement.If it is acceptable,thenitwillgofast.Ed Morris also discussed the capacity rate and energy rate. For Interim Agreement Capacityto North 10 MWCapacitytoSouth50MWEMITCR=60 MW For Capacity Rate =16.5%of Cost Tl "-EMITOR E>Reo}use=(0.166)(68,200) 60,000 =$0.187 per kw-mo Cost assumption of $68,200/mo.for interim operation to be fi- nalized in interim agreement. 9614/387 AFIOC Minutes May 15,1985 Page 4 NN\ 83.5%of Cost Kwh sales @ 30%Load Factor For Energy Rate =83.5%of Cost Demand x hours x 30% =83.5%of Cost EMITCR x hours x 30% =(.835)(68,200)x 100 c/$(60,000)(730)(0.3) =0.43 c/kwh Afzal Khan then discussed the remaining Intertie start-up/testingplan.He is planning to arrange a meeting with Dan Homer,GeneralElectricfieldengineer,to sort out various questions concerningGeneralElectricSVS. The Committee then took the issue of Alaska Electrical Utilities Mutual Assistance (A.S.C.C.)based on a letter to Afzal Khan fromLarryWolf(both from Alaska Power Authority).The letter is attached.Mike Massin noted that A.S.C.C.intends to get moreinvolvedinitsfunctionthanbefore.A.S.C.C.is supported by alltheutilities.The Committee believes that A.S.C.C.is entirely a different group.After a lengthly discussion,the Committee concluded that the functions of both A.S.C.C.and Anchorage/Fairbanks Intertie are not the same.It is not appropri- ate to mix both Committees.The Committee concluded that these two groups can interact through the minutes from the meetings.Bob Orr suggested that the chairman Mike Massin attend Manager's meetingswithEdMorris.John Marshall joined the meeting at 1:15 p.m. Turning to formal actions of the Operating Committee,Afzal KhanmotionedthattheIntrimMITCRcostbesharedequally(50-50) between Northern and Southern groups.Bob Orr seconded the motion. The motion was carried unanimously.Mike Massin suggested a letter'be sent to A.S.C.C.regarding interaction through the minutes fromthemeeting.Bob Orr motioned and Sam Mathew seconded'the motion.The motion was adopted unanimously. Chairman-Mike-Massin_requested-MarvinRiddle_te-give-a_report-on Dispatcher/Training Seminar at the next full Committee meeting. Chairman Mike Massin then directed the SCADA/METERING/COMMUNICA- TIONS SUBCOMMITTEE TO MEET ON TUESDAY,JUNE 11,1985 AT 1:00 P.M. AT THE MUNICIPAL LIGHT AND POWER ENGINEERING CONFERENCE ROOM for the purpose of reviewing the current status of the Anchorage-Fairbanks Intertie Data Link and particularly in the area of vendors,software and operation,and furnish the full Operating Committee with a written report on the meeting. 9614/387 AFIOC Minutes May 15,1985 Page 5 Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM MITTEE TO MEET ON TUESDAY,JUNE 11,1985 AT 9:00 A.M.AT THE MUNICIPAL LIGHT AND POWER ENGINEERING CONFERENCE ROOM for the purpose of working on schedules,accounting formats,and procedure for transfer of energy on the interconnected utility systems. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMAN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE-FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,JUNE 12,1985 at 9:00 A.M.IN THE TRAINING ROOM OF CHUGACH ELECTRIC ASSOCIATION, 5601 MINNESOTA,ANCHORAGE,ALASKA, Harry Beck,University of Alaska-Fairbanks,requested a copy of each of Intertie Relay Data Book and Operating Procedure Manual. Larry Colp motioned for the meeting to adjourn.Sam Mathews seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 2:00 p.m. |Respectively submitted, UfpeH.LhoAfzalH.Khan -Secretary Anchorage-Fairbanks Intertie Operating Committee Attachments: 1.June meeting Agenda. 2.Minutes from the April 23,1985 Dispatch Training Subcommittee Meeting. 3.University of Alaska-Fairbanks letter to Golden Valley Electric Association. 4,Minutes from the May 14,1985 Dispatch/Scheduling Subcommittee Meeting. Meter ing/Commun ications Subcommittee Meeting.6.Larry Wolf's letter to Afzal Khan.A.S.C.C.Mutual Assistance Committee. 7.Alaska Electrical Utilities Agreement Mutual Assistance, A.S.C.C. AHK/cde 9614/387 NS ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE AGENDA- WEDNESDAY,JUNE 12,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes Il.Approval/modification of agenda III.Committee correspondence and reports SCADA/Metering/Communications Subcommittee . Dispatcher/Training Subcommittee Dispatch/Scheduling Subcommittee Utilities Load Shedding Plan. Intertie Status Update (A.P.A.)MoonyeefdIV.Visitor comments related to items on agenda V.Old Business VI.New Business A.Recess and work session B SCADA/Metering/Communications C.Dispatcher/Training D.ODispatch/Scheduling E Reserves/Loadshed F.Interim Agreement G.Intertie Startup/Testing H Committee Budget I.Other VIT,FormaT Operating Committee action/recommendation=----= VII.Subcommittee assignments IX Adjournment Adjourn by 3:30 p.m. Meeting location:Chugach Electric Association oy 5601 Minnesota (Operations Training Room)&Anchorage,Alaska(907)563-7494 9313/383 eo,:MH wures Dispatch Training Subcommittee In Fairbanks -April 23,1985 ' NY The Dispatch Training Subcommittee met April 23,1985 at 9:00 A.M.at GVEA.Those attending were: John Aspenes UAF Bob Merritt UAF Marvin Riddle GVEA Allan Martin FMUS Ernie Jameison MEA=- AmePThedates were set for the Dispatcher Training at UAF.The first session was set for the period May 13th thru the 17th.This session will be the repeat of last year's session and the course content will not change. The second session will be the period June 3rd thru the 7th.This will be the advanced course. The University has stated they could only handle two sessions this year due to other commitments. For the advanced session the utilities have defined a general course outline. .This includes the following: SCADA -Discussion of types and methods of control. AGC -To include time error correction -frequency bias,ACE -how it isderived,how it is used. Rotating Machinery GT/GT Regenerative Units Combined Cycle Steam Hydro These are to concentrate on economic dispatch,response characteristic,start-up characteristics,restrictions and limitations on types of units. System Economic DispatchLossCalculationusingB matrix,on line load flows. Pool Coordination Power Transactions &Wheeling Power===Petermination-of"Operating Reserves ee Pool Planning &Operating Problems Stability John Aspenes will contact AML&P to determine if their consultant would be available to participate in the training. GVEA will allow use of their on-line load flow for demonstration purposes eee and course instruction. oe The utilities will handle their own accomodations. The fee will be the same as last year -$750/person. & The following utilities have committed to the listed numbers of people for each session: First Session Second Session MEA 3 MEA 2 FMUS 4 FMUS 2 GVEA 3 GVEA heAMLeP=.7)AMLeP 867 G) CEA 0 CEA 0 Minutes submitted by:Marvin Riddle |(WUTES s UNIVERSITYOF ALASKA FAIRBANKS Fairbanks,Alaska 99701 May 3,1985 Mr.Marvin Riddle Golden Valley Electric Association P.O.Box 1249 Fairbanks,Alaska 99707 Dear Marvin, As noted in your minutes of April 23,1985,we plan to offer a Dispatcher Training session May 13 through May 17 which will be a repeat of last year's program.An advanced seminar will be presented June 3 through June 7.Both will be at the University of Alaska-Fairbanks. Bob Merritt and I will be presenting the two seminars again this year.The general course outline is given in the April 23 minutes. The fee will be $750/person per seminar with the attendees taking care of their own accommodations. Thanks for your support. Sincerely, Garten Caporen-John Aspnes,Head Department of Electrical Engineering 233 Duckering Building University of Alaska-Fairbanks Fairbanks,Alaska 99701 ee(907)-474-7137- JA:DP:1796 .@ DISPATCH SCHEDULING SUBCOMMITTEE May 14,1985 The meeting was held in the Municipal Light &Power conference room,1200 E.Ist Avenue,and convened at 9:00 A.M.The following persons were present at the meeting: Larry Walls,Chugach Electric Association Ray Dunean,Chugach Electric Association Dan Rice,G-C Hank Nikkels,Municipal Light &Power Marvin Riddle,GVEA Pete Smithson,Municipal Light &Power The interim method of billing,reconciling and controlling theintertieuntilallotherrequiredhardwareisinstalledisas follows: Municipal Light &Power will control tie line to CEA at Plant II,GVEA will control tie line to CEA at Healy. Starting tie line bias at GVEA 2.0 MW/.01Hz,MLA&P 5 .OMW/.01Hz Accounting and reconciliation twice per day (on peak-off peak) KWH +Losses at Douglas =Net KWH KWH -Losses at Healy Per Company Column-- Sum all in and all outs Net KWH at Douglas -Cantwell =Net Interchange. Inadvertant for GVEA is +Cantwell For inadverdent account the established off peak times are 2100-0500.All other times are established as on peak. Losses will be established using loss table provided by G-C/APA The scheduling will be done through Hank Nikkels,ML&P,or Pete ° Smithson,ML&P,for the southern controller.The CEA schedule will be negotiated and verified by the purchasing utility.Prior to-scheduling-with the area controller.Marvin Riddle asked--when==-------ML&P power dispatching would be manned.Hank Nikkles said approximately one month,and scheduling would be with him or Pete until transferred to Dispatching.Operation scheduling at GVEA will be with Marvin Riddle. F at:Dispatch Scheduling Subcommittee NsMay14,1985 Page Two Intertie Billing Reconciliation: Out from Douglas 51,800 KWH In at Douglas 22,200 KWH(29,600)NET In at Healy Out at Healy 15,400 KWH In at Healy 25,400 KWH 10,000 KWH NET 18 ,400 CWS Load 28,400 -(GVEA)NET -Difference 1,200 Each participant shall state in writing to the other participants who in their organization is authorized to establish schedules and prices for transactions. For the Committee Hank Nikkels Municipal Light &Power HN/Is SCADA METERING/COMMUNICATIONS SUBCOMMITTEE MEETING MINUTES RECEIVenECEIVEL May 14,1985 MAY 2 2 1985 A KA POWE { ;The med Hing was es tTed'to order by chairman Bob Orr at 1:20 P.M.in the Municipal Light &Power conference room,May 14,1985.Those present were: Bob Orr,Golden Valley Electric Association Afzal H Khan,Alaska Power Authority Dan Rice,Gilbert Commonwealth Pete Smithson,Municipal Light &Power Robert Day,Municipal Light &Power Jim Hall,Matanuska Electric Association Larry Shalls,Chugach Electric Association Vance Cordell,Chugach Electric Association Kevin D.Parsons,Chugach Electric Association Marvin Riddle,Golden Valley Electric Association The meeting started out with Bob Day giving a report on the present status of Municipal Light &Power's vendor system control in reference to the implementation of the data link.The Municipal Light and Power SCADA system is expected to ship late June.That equipment will be as complete as possible as far as the intertie data link is concerned,with final testing to occur at a yet to be named date,depending on when Landis and Gyr is ready.Threeoptionsexistforthefinaltesting:z 1.Testing may be performed from ML&P,Anchorage to Landis and Gyr,San Jose. 2.SCI will investigate the short term lease of an 11/44,systemtoperformthetestingand.verification in California on alocalbasis. 3 A possibility exists that SCI in California may have an 11/44 system on the factory floor for another project and will be able to perform the testing and verification on that machine. That was followed up by Bob Orr giving a report on the status of the intertie from the Landis &Gyr/Golden Valley Electric perspective. The Chairman then called on Kevin Parsons from Chugach Electric to give a report on Chugach's implementation and discussion ensued that indicated that Chugach is presently involved with writing a : DECNET emulation to provide end node only.This means that-Chugach > will be a radial link of the loop.Chugach expressed a desire to have a coordination meeting between the various vendors and Mr. Parsons to resolve and discuss any problems with theirimplementation. Page 1 of 4 OFGre It was indicated that Chugach has successfully added or successfully come up with a method to add a single DMR 11,but has a hardware problem in slot space availability for Chugach to add the second DMR 11 to provide for a loop network.." Vance Cordell voiced the CEA concern about the APA/CEA reimbur- sement.That question was tabled for a later date and APA will be setting up a meeting with them to discuss that.ML&P noted that this modification from the specification as from the April 24,1984 document produced by APA and the operating committee requires addi- tional hardware for the consideration of CEA's radial system. Afzal Khan,APA,suggested that ML&P/CEA and APA have a meeting which will be held 9:00 A.M.Friday at ML&P to discuss the actual hardware requirements of the system as proposed.In the area of communications,there is a 9600 baud link established to CEA at their new dispatch center from ML&P's present computer location.This will provide CEA with a link to ML&P's SCADA system via CRT so that they may get information concerning the status of Teland's sub, Douglas substation and the ML&P/CEA intertie. It was noted that the modems need to be ordered or produced from DIVCOM to implement the 9600 baud data link between the Golden Valley and ML&P. Voice communications are in and working well.It was noted that it would be desirable to get an extension into ML&P's switch so that Golden Valley can communicate with PlantI/Plant II during the off hours.In addition,this would provide Golden Valley the ability to dial Chugach through ML&P's local switch on a local phone call, rather than the long distance.Bob Orr said he would speak to DIVCOM about getting the modems installed and also find out what will be required in order to implement the additional voice com- munication to provide an extension off ML&P's switch.ML&P indi-cated that this would not be a problem for them. Bob Orr then voiced a question about voice communications with MEA,Homer,etc.Jim Hall indicated that when the need becomes a realitythentheywillbeinstallingthoselinksasrequired. The present system as proposed by Landis &Gyr puts testing of the intertie data link in the October/November time frame.Due to this delay of the link,interim operating procedures will need to be developed by this committee or by other committees.The general intertie committee should assign some work duties to develop these procedures to one or more of the subcommittees. Khe Page 2 of 4 Bob Orr and Marvin Riddle then gave a report on the testing start-upwhichoccurredtheendofAprilforapproximatelyoneweekwherethe tie was operated.Power was successfully shipped both north and south.The line was picked up from the southern end,operated and then when attempting to pick up the line from the northern end, there was a failure in the SVS at Healy and as of yet the problem has not been corrected. Bob Orr noted that the voltages in Cantwell seemed to be 30-40% voltage flicker and this indicates a real control problem on the SVS system.In addition,the SVS metering PT's have a real problem as they are on the switchable bus.An additional set of PT's is needed to solve this problem.Bob Day reported on some control problems with the SVS system at Teland in that there is no feed back to indi- cate the present set point of the SVS system. Afzal Khan,APA,acknowledged receipt of the letter from ML&P con- cerning such and some discussion will be ensuing at the Friday meeting concerning this. Metering performance during the test was discussed.Errors were approximately 1.2 megawatt hours over the 51.8 megawatt hours sent north and 22.2 megawatts that were sent south.This 1.2 megawatt error included losses. The subcommittee directed the secretary to indicate to the general operating committee that a better and more substantial report on the status of the data link will be given next month,as the vendor meeting is scheduled for the 17th of May.This meeting was for- merly scheduled for the first part of May,but was postponed due to illness of one of the principals from Landis &Gyr. The question from the Chairman,then,was what the subcommittee viewed as the next important task for this committee to attack.It was noted that some 'spare bubble memories were needed.Jim Hall has some spares available,but in any case,each party who is going to be reading these meters needs to have some spare bubbles for swapping purposes.It was indicated that the bubble memories may not roll-over or be a circular file,as the instructions indicate to erase them before they are replaced into service.The implication is that they may loose data or trash data if they are allowed to overwrite previous information. The question then came up as to where the bubble translators are located.Apparently APA was to have two of these devices,but it is unknown as to their present whereabouts.Afzal Khan indicated thathewillfindoutandreporttothecommittee. Page 3 of 4 It was then indicated that the next topic for this committee would be to provide and review metering information and procedures.Dan Rice formulated a question on data collection,and how this ties into the dispatch committee.It will be necessary for the dispatchcommitteetoformulatesomeformsandregulationsorrulescon- cerning data collection during the intertie so that this committee may take that data and verify that SCADA systems,metering systems are operating and indicating proper quantities.There may be a needofajointdispatch/SCADA metering subcommittee in order to resolve these.This will not be too much of a problem as many of the per- sons on each committee are the same person from each utility. Dan Rice indicated the loss calculations are near to completion,but some parameters need to be verified before the load flows will be run. Bob Day motioned that the meeting be adjourned.The motion was seconded by Vance Cordell.The motion carried unanimously at 3:05 P.M. Respectfully submitted for the committee. Robert Day Municipal Light and Power RD/Is Page 4 of 4 Muule MEMORANDUM State of Alaska TO: FROM: & Afzal H.Khan oate:May 24,1985 Director/Systems OperationsandEngineering|FILE NO: TELEPHONE NO: Larry Wolf fe!susvect:A.S.C.C.Mutual Operations Engineer/Solomon Assistance Committee/ Anchorage-Fairbanks Intertie Operating Committee As the A.S.C.C.Mutual Assistance Committee fis concerned with utility interaction on a statewide basis and primarily during an emergency situation,and the intertie operating committee isconcernedwithmanyofthesameissuesofutilitiesprimarilyinvolvedwiththeintertieandwhiletheactiveagenciesandquite often agency personnel are the same for both committees,would youaddresstheoperatingcommitteetoseeiftheyfeelitwouldbeof any benefit or convenience to combine the efforts of these twocommitteesorpursueourgoalsinacoordinatedeffort.If thereisaninterestexpressedalongthisdirection,I,as a member oftheMutualAssistanceCommittee,will be glad to work with the appropriate personnel to further coordinate this effort. Enclosure:Copy of Mutual Assistance Agreement LW:it 02 O01A(Rev 10/79) 9410/380 ALASKA ELECTRICAL UTILITIES AGREEMENT MUTUAL ASSISTANCE A.S.C.C. 5126/028 (1) osA.S.C.C. Sw ALASKA ELECTRICAL UTILITIES MUTUAL ASSISTANCE AGREEMENT A.S.C.C. I.Purpose II.Terms of Agreement III.Utilities Covered Under This Agreement IV.Payment V.Liability VI.Termination VII.Procedure for Securing Help VIII.Coordinating Office Procedure IX.Mutual Assistance Action X.Communications XI.Suggestions XII.Reimbursement 5126/028 (2) @A.S.C.C. I.-PURPOSE It is the purpose of this agreement to provide for reciprocal arrangements for rendering emergency assistance to the utilities Ssianatory hereunto,whenever said utilities are unable to make timely restoration of service due to emergency conditions and/or situations.The utilitie(s)in need will make the sole determina- tion as to what constitutes an emergency and which signatory utility will be called for assistance. II.-TERMS OF AGREEMENT (a)All calls for emergency assistance will be made on behalf of -the utility in need through its General Manager or in hisabsence,his designee.: (b)Upon receipt of a call for emergency repair service,theutilitycalledwillmakethesoledeterminationastothe manpower,equipment,supervision and support that it can provide to the utility in need.. (c)The utility called will make every effort to expedite repairs to the system of the utility in need and will.not do switchingorenteranysubstation(s)unless accompanied by qualified personnel from the utility in need. (d)All repairs made will be under the supervision of the utilityinneedandexpeditedthroughsupervisionprovidedbytheassistingutility. (e)Terms and agreements of the assisting utilities contract willremainineffectatalltimesandwillnotbecircumvented except by mutual agreement. ITI.-UTILITIES COVERED UNDER THIS AGREEMENT Any and all Alaska Electrical utilities signatory to this agreement. IV.-PAYMENT The party for whom the work has been performed shall reimburse theperformingpartytheactualcostsandexpensesoftheworkper-formed in accordance with customary utility accounting procedures, and,in addition,overheads reasonably allowable,within 30 days of receipt of an itemized statement of such costs and expenses. 5126/028 (3) aeSeA.S.C.C. V.-LIABILITY Each party agrees that the performing party shall not be held liable for any damage or consequences resulting from: (a)Work Performed (b)Injury to Employees(c)Damage to Equipment and/or Facilities(d)Refusal to Render Service (e)Delay in Making Personnel and Equipment Necessary VI.-TERMINATION This agreement will remain in effect until any party signatoryhereuntonotifiesallotheraffectedparties30dayspriorto termination,in writing. VII.-PROCEDURE FOR SECURING HELP WHEN AN EMERGENCY ARISES A.Survey the extent of damage and determine -as early aspossible-the manpower and equipment needed.(USe of air-craft is highly recommended if weather allows.)QB.If the emergency is of a small scale and only your utility iseffected,arrange directly with neighboring manager(s)forimmediatehelp.Otherwise notify the coordinating officewhichwillgetyouhelpandkeepadispatcherondutyaround the clock throughout such emergencies. C.Phone numbers for the coordinating office are listed below: 1. 2. D.If normal telephone and radio contracts cannot be made - utilize the Alaska State Troopers. oo MTTT =COORDINATING OFFICE PROCEDURE The person at the coordinating office receiving any call for assistance will attempt to learn: A.Nature of the emergency B.The severity of the situation. C.What has been done 5126/028 (4) A.S.C.C. D0.Who has been contacted E.What help the utility thinks it needs. F.What amount and type of equipment,materials and person- nel are needed first. IX.-MUTUAL ASSISTANCE ACTION The Mutual Assistance Program Personnel receiving the originalmessagewillinstituteimmediateactiontoenlistappropriatehelpandgetittothedesiredlocation:(personnel,equipment & material). X.-COMMUNICATIONS Communications will be maintained regularly between the coordinat- ing office and the distressed utilities. XI.=PRACTICAL SUGGESTIONS DURING A DISASTER A.When disaster strikes your system,you will do what seems besttoyouandtherestofuswillhelpyouasyouthinkisbest.The following are some observations made since out 1964 Earthquake experience. B.There is no substitute for hydraulic aerial equipment,pref-erably combination digger-derricks with basket plus a pole trailer during a disaster. C.Contact for an airplane or helicopter to patrol your system.Either the Manager,Superintendent,or Foreman should fly thesystemtosurveytotaldamage.Use the system map in patrol-ling and mark damaged areas,also approximate the number of poles needed. Some utilities did not realize for a day and a half how badlytheyweredamaged,thereby losing that much time in securing more help. DO.There is a limit to the length of time men can work effective- ly and safely without rest in bed. Around-the-clock work,in shifts,is logical is a situationexpectedto.be cleared up within two or three days,but if itlookslikealongerpull,daylight-to-10:00 p.m.probably willpaybetterforallconcerned.Arrangements will have to be made for food and lodging by the local utility. 5126/028 (5) cocumenpotasA.S.C.C. E. M. \ Truck and equipment service may be a problem.Filling sta- tions may be unable to pump gasoline.You should be able to make arrangements with a distributor to make tank truck deliveries to your vehicles at a convenient location.Also you may want to utilize you mechanic just in case some of the trucks need some work. On of the big mistakes is to yield to pressure from individu- als for special attention.Little progress can be made in cleaning up major damage when crews are required to run fromoneendofthesystemtotheothertryingtosatisfyindividu- als who demad special attention without justification. Experience has shown the wisdom of giving a crew respon-sibility foe work on a given sub-station and letting them workoutthefeederlinestotheendorsectionalizingpoint;then come back and restore service on single phase lines or taps off the feeder. Some utilities feel that it is good to have one or moretwo-man crews for dispatching to locations where specialhazardsmayexistorwherecriticalloadsshouldbegiven special consideration.When not on such work they can be used to repair individual services. Maintain a list of names of who is working with whom andwhere,and also their radio call letters.(This can be put onasmalltagandputonthemapwithastickpin.) Make arrangements with your.county or State Highway crews toblockoffsectionsoftheroadswhennecessary.One of thebigproblemsinrestoringservice,especially in earthquake areas,are sightseers. If crews will be needed for any length of time the dispatcherwillremindtheCooperativesendinghelptohavethemenbring extra clothing. Inform crews to make noted of small things needed to be done at a later date. If possible,patrol the lines before energizing.Clear all switching with the local dispatcher. It is recommended private line telephones be installed in eachutilityandthestatewideofficebeinformedofthenumber. Each utility should have several extra system maps,also some sub-station maps and provide one to each crew working. 5126/028 (6) souNesA.S.C.C. XII. a If at all possible,try to patrol all vines and take care of all hazardous situations before releasing extra crews. Each visiting crew will be accomplished by a local utility employee. -POSSIBLE METHOD OF REIMBURSEMENT The electric utility sending help will pay their own men according to their own pay scale and contracts and in turnbilltheCooperativereceivingthehelpfortheactuallaborcostplusactualoverhead. Actual travel and living expenses of men and equipment incur-red by assisting another utility is to be invoiced jn the actual amount. Mileage shall be charged at 20 cents per mile on cars andpick-ups for every mile driven from the time they leave theirownUtilityanduntiltheygetback.Daily charge for theseunitswillbeaslistedonthedatainformationsheetfrom each utility. Mileage shall be charged at 40 cents per mile for digger-derricks,aerial devices and all terrain equipment but only onthemilesdriventoanfromtheutilityreceivingthehelp.The miles that are driven while actually working will be considered part of the daily charge.The utility receiving the help will furnish all petroleum products. Charges to be made for such items of special equipment such asportablegenerators,boats,cranes,etc.shall be arrived at by authorization of the local utility official. It is not expected that any charge will be made for use oftoolsandworkequipment,but such supplies as sleeves,fuses,connectors,conductor,poles,etc.are to be invoiced at the actual cost. It is recommended that vehicle and_equipment be insured with aminimum$1,000 deductible collision and upset insurance.(Incaseatruckwouldbewreckedthe$1,000 deductible would bepaidbytheutilityreceivingthe'help.)Make sure yourinsurancecoversyourmanpowerwhileworkingonanother system. While these charges may or may not reimburse all utilities for the total expense,consideration shall be given to the fact that a utility hit with a major disaster will experience considerable expense,and,over the years,the exchange of labor and equipment 5126/028 (7) A.S.C.C. % will level off and be equalized.If it doesn't,be thankfulbecauseyouhaven't been hit. Utility Name: Name &Title of Authorized Representative: Date: 5126/028 (8) °ee Bon &DEVELOPMENT OF LOSS TABLE* ASSUMPTIONS Most of the data and assumptions required to calculate the loss tables will be taken from the "Load Shedding for Spinning Reserve"report prepared March 1,1985.The assumptions are listed below: 1.Study Period -The study period will include Summer 1985 and Winter 1985/1986 conditions. 2.System Load Levels -Refer to Exhibit 2 of the Load Shedding Report.This exhibit needs to be updated to show Winter 85/86 peak loads.Unless advised otherwise,85/86 peak load will be assumed to be 5 percent greater than the 84/85 peak load.Loss tables will be developed for 40 percent,75 percent, and 100 percent load levels. 3.System Configuration -It is assumed that the transmission configuration will remain unchange through the study period.The Anchorage and Fairbanks configurations are shown on Exhibit 1,Sheets 1 and 2 of the Load Shedding'. Report.The following Anchorage area details should be noted: a.AMLP Plant 2 connected to the CEA Beluga -University 230 kV circuit. b.AMLP 115 V transmission reconfigured to include Substations 7,8 and 12 and removed of Substation 11. c.CEA University -APAd Anchorage 115 kV circuit operated normally open. d.A 30 MVAR reactor inservice on the eastern terminal of the CEA 230 kV submarine cable. 63/DLTA/D2 e. f. i. je CEA Pt.MacKenzie Substation modeled with a Split 138 kV bus. 730 CEA Pt.Mackenzie Teeland circuit operated at _L38kV. CEA Beluga Pt.MacKenzie circuits 1 and 2 operated at 138 kV. APAd Eklutna -MEA Dow Tap 115 kV circuit operated normally open. AMLP Unit 8 inservice.It is assumed that CEA's entitlement in this unit is 40 MW in the study period. The HEA Soldotna 39 MW gas turbine will be assumed inservice. The HEA Soldotna -Fritz Creek 115 kV circuit will be assumed not inservice. The following Fairbanks area details should be noted: a.The GVEA 69KkV circuits between Gold Hill and Zehnder are configured as shown on Exhibit 1,Sheet 2 of the Load Shedding Report. 00b.The Cantwell Substation is assumed inservice.ais kW 85/86 peak load will be assumed,unless advised otherwise. c.The Gold Hill 100 MVA,138/69 kV transformer and the Gold Hill SVS are assumed inservice. The GVEA Gold Hill -Ft.Wainwright 138 kV circuit is assumed not inservice during the study period. 4.Generation -The winter and summer generator capabilities and the generator dispatch order will be the same as used in the Load Shedding Report, Exhibits 3,4 and 5.The only exception is the Soldotna unit will be included on Exhibit 4. 63/DLTA/D2 5.Loss Zones -The loss tables are to show the losses fok the following zones. a.Douglas -Cantwell -Healy 138 kV line. b.Healy -Zehnder (Healy -Nenana -Gold Hill 138 kV circuit,Gold Hill - Musk OX Tap -Zehnder 69 kV circuit,Gold Hill -Chena Pump Tap - International Airport -Peger Road -S.Fairbanks -Ft.Wainwright 69 kV circuit,and Ft.Wainwright -Hamilton -Zehnder 69 kV circuit.) c.University -Douglas (University -Plant 2 -Beluga 230 kV circuit,Beluga -Pt.MacKenzie iieKv circuits 1 and 2,Pt.MacKenzie -Teeland 245 5Kv circuit,Teeland -Douglas 138kV_circuit, Pt.MacKenzie -Pt.Woronzof 138 kV circuits,Pt.Woronzof - International 138 kV circuits 1 and 2,and International -University 138 kV circuit). d.Soldotna -University (Soldotna -Quartz Creek -Daves Creek -Hope - Portage -Girdwood -Indian -University). @,thin _ 6.Interchange Transactions -The purposes of the loss tables are to show: incremental transmission losses on the intertie and on the CEA and GVEA interposing transmission systems.Therefore,power interchange transactions were assumed between AMLP and FMUS to provide a calculation of losses in CEA and GVEA with a single load flow run.Where it was not possible to schedule a transaction between AMLP and FMUS because of load or generation constraint then the transaction was assumed between AMLP, GVEA,and FMUS.The load flow cases proposed are summarized on the attached "Load Flow Case Index." 63/DLTA/D2 LOAD FLOW CASEINDEX +Sell/-Buy Matrix &Intertie Schedule -MW Case A-F No.Case Description AMLP CEA INTERTIE GVEA FMUS 1 Base Case -100%Load 0 0 0 0 0 2 Case 1 with 10 MW on Intertie 10 0 10 0 -10 3 Case 1 with 20 MW on Intertie 20 0 20 0 -20 4 Case 1 with 30 MW on Intertie 30 0 30 0 -30 5 Case 1 with 40 MW on Intertie 40 0 40 -10 -30 6 Case 1 with 60 MW on Intertie 50 0 50 -20 -30 7 Case 1 with 60 MW on Intertie 60 0 60 -30 -30 8 Case 1 with 70 MW on Intertie 70 0 70 -40 -30 9 Case 1 with -10 MW on Intertie -10 0 -10 0 10 10 Case 1 with -20 MW on Intertie -20 0 -20 0 20 11 Case 1 with -30 MW on Intertie -30 0 -30 0 30 12 Case 1 with -40 MW on Intertie -40 0 40 10 .30 13 Case 1 with -50 MW on Intertie -50 0 -50 20 30 14 Case 1 with -60 MW on Intertie 60 0 -60 30 30 15 Case 1 with -70 MW on Intertie -70 0 -70 40 30 16 Base Case -75%Load 0 0 0 0 0 17 Case 16 with 10 MW on Intertie 10 0 10 0 -10 18 Case 16 with 20 MW on Intertie 20 0 20 0 -20 '19 Case 16 with 30 MW on Intertie 30 0 30 -10 -20 20 Case 16 with 40 MW on Intertie 40 0 40 -20 -20 21 Case 16 with -10 MW on Intertie ©-10 0 -10 0 10 22 Case 16 with -20 MW on Intertie -20 0 -22 0 20 23 Case 16 with -30 MW on Intertie -30 0 -30 10 20 24 Case 16 with -40 MW on Intertie -40 0 -40 20 20 25 Base Case -40%Load 0 0 0 0 0 26 Case 25 will 10 MW on Intertie 10 0 10 0 -10 27 Case 25 with 20 MW on Intertie 20 0 20 .-10 -10 28 Case 25 with -10 MW on Intertie -10 0 -10 0 10 29 Case 25 with -20 MW on Intertie -20 0 -20 10 10 30-58 Same and Cases 1 through 29 except with Healy generator off. 59 75%Load -Sell from Soldotna 0 20 20 0 -20 60 75%Load -Sell from Soldotna 0 30 30 -10 -20 61 40%Load -Sell from Soldotna 0 20 20 -10 -10 63/DLTA/D2 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE MINUTES WEDNESDAY,APRIL 17,1985(At Municipal Light and Power,Anchorage) Attendance: James D.Hall Matanuska Electric Association John C.Marshall Chugach Electric Association Ray L.Duncan Chugach Electric Association Larry Walls Chugach Electric Association Robert Orr Golden Valley Electric Association Marvin Riddle Golden Valley Electric Association Keith M.Sworts Fairbanks Municipal Utilities System Larry Colp Fairbanks Municipal Utilities System Sam Mathews Homer Electric Association Mike Massin Anchorage Municipal Light and Power Ed Morris Alaska Power Authority Afzal H.Khan Alaska Power Authority Howard Thacke Alaska Power Authority The meeting was called to order by Chairman Mike Massin at 9:35 a.m.in the Municipal Light and Power main conference room. Bob Orr motioned that the minutes be adopted as written and John Marshall seconded the motion.The motion was approved unani- mously. Mike Massin then motioned for the agenda to be adopted with modi- fication -VI F Intertie Agreement/Testing.John Marshall seconded the motion and it was approved unanimously. Under Committee correspondence reports,Mike Massin noted that the Alaska Power Authority had sent the Chugach Electric Association a letter indicating that the need to utilize CEA's microwave link between Teeland substation and the CEA's headquarters for Intertie protective relaying is no longer required.Mike Massin also reported that the Golden Valley Electric Association had sent a letter to the Alaska Power Authority regarding GVEA's concern aboutSVSoperationalcharacteristics. Bob Orr noted that he was unable to schedule a SCADA/Communications Subcommittee meeting.Final functional requirements from the vendors has been received and are in the process of being reviewed. He also noted that discussions among the vendors Systems Control,Inc.(SCI)and Landis and Gyr are going good,but there is a possible delay on the Data Like portion.A meeting between Systems 9313/383 | AFIOC Minutes April 17,1985 Page 2 \ Control,Inc.(SCI)and Landis and Gyr will be arranged to discuss Data Link. Chairman Mike Massin directed the Dispatch/Training Subcommittee to reschedule a meeting. Marvin Riddle gave a report on the meeting held by the Dispatch/- Scheduling Subcommittee.This meeting was held on April 16,1985attheMunicipalLightandPowermainconferenceroom.(Marvin also furnished the Operating Committee with a set of minutes whichareattached.)He noted that the subcommittee had reviewed the switching orders submitted by the Alaska Power Authority. Marvin also provided the operating committee with a set of minutes from the Reserves/Loadshed Subcommittee meeting.This meeting was held on Tuesday,April 16,1985 at 1:00 p.m.at the Municipal Light and Power Engineering Conference Room. Afzal Khan,from the Alaska Power Authority,was then asked to provide the Operating Committee with a status report on the Anchorage-Fairbanks Intertie construction.Afzal Khan and C. Parrish furnished an Intertie Status update.Alaska Power Author- ity requested Gilbert/Commonwealth to finalize the Operating Procedures Manuals.Afzal Khan advised that the Operating Proce- dures manuals will be available for distribution at the next Operating Committee meeting.Regarding line segment loss applica- tion table or tables to a resolution of whole "megawatt",Alaska Power Authority discussed with Gilbert/Commonwealth.Once Gilbert/Commonwealth is given permission to develop tables,the tables could be available in two weeks.Regarding operator's diagrams,Afzal Khan reported that Gilbert/Commonwealth is supposed to send a Mylar and ten Blue Lines.They will be distributed once received. CEA advised that some work would have to be done on their system in order to be able to do the switching needed to energize the trans- mission line to Healy.CEA can do the work and be ready by Friday, April 19 if the Alaska Power Authority will pick up the extra costs of a helicopter for about 4 hours and 2 linemen for about 4 hours. Estimated to be about $3,000.00.Afzal Khan advised to go ahead with this.GVEA agreed to do the switching on April 19,1985.CEA asked for another fly-by of the transmission line from Douglas toHealybeforeenergizing.Arrangements were made to do this at 8:00 a.m.on April 18,1985.John Marshall and another CEA representa- tive will accompany M-K representative.M-K agreed to reconfirm new switching schedule with dispatchers of utilities other than GVEA.Discussed low bus at Healy Substation.GVEA wants the bus raised.Alaska Power Authority is waiting on results of tempera- ture readings on the SVS bus penetration plates in the building during SVS checkout in order to decide if plates need to be changed also.Both items could be done at one time.GVEA expressed 9313/383 AFIOC Minutes April 17,1985 Page 3 \ concern that waiting may cause the Intertie to be taken out of service to do the work.The maximum temperature readings at Teeland were reported by start-up crew to be 108°F.Plans are to also measure at Healy.GVEA advised that configurations at these two sites are different. No visitors were present. The Operating Committee had no old business to conduct at the meeting.It was noted that the Operating Committee has been in existence for two years. Turning to new business,Chairman Mike Massin requested Ed Morris, from the Alaska Power Authority,to furnish Intertie Agreement update.Ed Morris discussed the Intertie costs,insurance and combining Interim Agreement with full Intertie Agreement.Mike Massin noted that as per Article 28,Intertie Agreement,they can not do anything until REA approves it.Ed Morris then asked how Tong will it take to get REA approval.It was noted that draft is not sent by GVEA,HEA,CEA and ML&P to REA for approval.Ed Morris also asked if APU has any requirements.John Marshall left the meeting at 10:30 a.m.Also,it was noted that the operation and maintenance budget should be prepared fourteen months prior to submittal to the legislature.GVEA,ML&P,and CEA should submit budget for the year 1986-1987.Ed Morris asked the Committee,is there any problem in coming up with an interim budget.The Operat- ing Committee will be reviewing insurance requirements. The Operating Committee then went into work session at 11:35 a.m. and return to full session at 12:00 noon. Turning to SCADA/Metering /Communication,Bob Orr indicated that the vendor data will be available for next Operating Committee meeting. The committee began a brief discussion on Dispatcher/Training and directed the subcommittee to meet again at 9:00 a.m.on April 23, 1985 at the Golden Valley Electric Association Dispatchers Training Room in Fairbanks along with Dr.John Aspen and Mr.Robert Merrit, both from the University of Alaska -Fairbanks. The Dispatch/Scheduling Subcommittee Report by Marvin Riddle was accepted by the Committee.It was noted that further discussion is required on schedules,accounting formats,purchase of power and line loss tables. The Reserve/Loadshed Subcommittee Report by Marvin Riddle was accepted by the Committee.Mike Massin suggested that the Subcom- mittee write a letter to Chugach Electric Association regarding load shedding on the south side.Mike Massin also suggested that the Subcommittee give another look at load shedding. 9313/383 AFIOC Minutes April 17,1985 Page 4 \ Turning to Formal Operating Committee actions/recommendations, Chairman Mike Massin motioned that.the Operating Committee direct the Alaska Power Authority to determine interim power flow maximumvalues(north and south)for the following conditions. 1.Gold Hill substation transformer out of service 830 normally open No generation at Eklutna One unit operating at Eklutna Two units operating at Eklutna fo)on>wN°°°eeContingency -Teeland/Pt Mackenzie out of service Bob Orr seconded the motion.The motion was adopted unanimously. Chairman Mike Massin recommended that the Intertie Operating Committee draft a letter to Mr.Virgil Gillespie,General Manager, Fairbanks Municipal Utility System expressing the Operating Commit- tee's appreciation for the services provided by Mr.Keith Sworts. Bob Orr motioned that a letter be sent to Mr.Virgil Gillespie. Sam Mathews seconded the motion.The motion was adopted unanimous- ly. Turning to subcommittee assignments,Chairman Mike Massin directed the DISPATCHER/TRAINING SUBCOMMITTEE TO MEET AT 9:00 a.m.ON APRIL 23,1985 AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION OPERATIONS DISPATCHERS TRAINING ROOM for the purpose of reviewing the 1985 Dispatcher Training Program.Mr.John Aspnes and Mr.Robert Merritt from the University of Alaska-Fairbanks will be in attendance at this meeting. Chairman Mike Massin then directed the SCADA/METERING/COMMUNICA- TIONS SUBCOMMITTEE TO MEET ON WEDNESDAY,MAY 8,1985 AT 9:00 A.M, AT THE MUNICIPAL LIGHT AND POWER ENGINEERING CONFERENCE ROOM for the purpose of reviewing the current status of the Anchorage-Fairbanks Intertie Data Link and particularly in the area of vendors,software and operation,and furnish the full Operating Committee with a written report on the meeting. Chairman Mike Massin also directed the DISPATCH/SCHEDULING SUBCOM- MITTEE TO MEET ON TUESDAY MAY 14,1985 AT 9:00A.M.AT THE MUNICIPAL LIGHT AND POWER ENGINEERING CONFERENCE ROOM for the purpose of working on schedules,accounting formats,and procedure for trans- fer of energy on the interconnected utility systems. The Operating Committee then proceeded to set the agenda for the next full Operating Committee meeting. 9313/383 AFIOC Minutes April 17,1985 Page 5 \ AS A REMINDER:THE SUBCOMMITTEE CHAIRMEN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE-FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE ON WEDNESDAY,MAY 15,1985 AT 9:00 A.M.IN THE MAIN CONFERENCE ROOM OF MUNICIPAL LIGHT AND POWER AT 1200 EAST FIRST AVENUE,ANCHORAGE,ALASKA. Keith said he enjoyed working with the members.Keith Sworts then motioned for the meeting to adjourn.Sam Mathews seconded the motion.The Operating Committee then unanimously approved the motion to adjourn at 1:30 p.m. Respectively submitted, Ho bhas. Afzal H.Khan -Secretary Anchorage-Fairbanks Intertie Operating Committee Attachments: 1.Alaska Power Authority letter to Chugach Electric Asso- ciation. 2.GVEA letter to Alaska Power Authority 3.Minutes from the April 16,1985 Dispatch/Scheduling Subcommittee meeting. 4,Minutes for April 16,1985 Reserve/Load Shed Subcommittee meeting. 9313/383 ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE -AGENDA- WEDNESDAY,MAY 15,1985 BEGIN AT 9:00 A.M. I.Adoption of prior meeting minutes Il.Approval/modification of agenda III.Committee correspondence and reports SCADA/Metering/Communications Subcommittee Dispatcher/Training Subcommittee Dispatch/Scheduling Subcommittee Utilities Load Shedding PlanIntertieStatusUpdate(A.P.A.)NIOAW>eo8e««©6IV.Visitor comments related to items on agenda V.Old Business VI.New Business Recess and work session SCADA/Metering/Communications Dispatcher/Training A B Cc D.Dispatch/Scheduling E Reserves/Loadshed F Interim Agreement G Intertie Startup/Testing H Other VII.Formal Operating Committee action/recommendation VII.Subcommittee assignments IX Adjournment Adjourn by 3:30 p.m. Meeting location:Municipal Light and Power -Main Conference Room 1200 East First Avenue -Anchorage,Alaska(907)279-7671 9313/383 ALASKA POWER AUTHORITY 34 WEST 5th AVENUE -ANCHORAGE,ALASKA 99501 Phone:(907)277-7641 \(S07)278-0001 April 8,1985 RECEIVED APR 1 11985ChugachElectricAssociation 5601 Minnesota Drive,Pouch 6300 Anchorage,Alaska 99502 Attention Mr.Vance H.Cordell Subject:Anchorage-Fairbanks Intertie Teeland Substation Communications Draft Addendum -Intertie Maintenance Agreement Dear Mr.Cordell: This letter will confirm that as a result of our meeting on March 19,1985, it was agreed that the operation of the Anchorage-Fairbanks Intertie would be best served by relocating the existing microwave link between DepartmentofTelecommunicationssitesummitandChugachElectric's (CEA)headquarters building,and creating a direct microwave link between CEA's Teeland Substation and site summit. Accordingly,the need to utilize CEA's microwave link between Teeland Substation and the CEA headquarters building for Intertie protective relaying is no longer required.The proposed addendum to the CEA/Alaska Power Authority Teeland Substation Maintenance Agreement transmitted by your letter of February 25,1985,is therefore,not necessary. It is my understanding that CEA is working with Anchorage Municipal LightandPower(AML&P)regarding the exchange of SCADA information,and that CEA will advise the Power Authority of the plan for receipt and exchange of Intertie operating data from AML&P. If you should have any questions please give me a call. Sincerely, LYDavidR.Eberle Project Manager ;C Of lts TODRE/amh /4,SASS:(2 (a)cc:Ray Duncan,CEA Va DayMikeMassin,AML&P ;Bob Orr,GVEA [1s J fs"7esMikeRidge,Div.Com Dan Rice,G/C Lytle Miler,G/C Le [LLYN S a 7.woorl fy RECEIVED APR 1 11985 GOLDEN VALLEY ELECTRIC ASSOCIATION INC.Box 1249,Fairbanks,Alaska 939707 Phone 907-452-1151 April 5,1985 Dave Eberle Alaska Power Authority 334 W.Sth Ave. Anchorage,AK 99501 Subject:SVS Operational Characteristics Dear Dave: Recently the SVS operational characteristics were made known verbally at the February 1985 Operating Committee Meeting.A copy of these minutes are attached. As stated to you previously,GVEA is extremely concerned with the operational characteristics of the SVS to the extent that they do not apprear to be acceptable.The concern mainly lies in the start-up characteristics.We don't know what the shut-down characteristics are so we cannot comment on that now. The SVS start-up characteristic concern is with both the Gold Hill unit and the Healy unit.Following is a listing of our concerns: 1.One of the original operational requirements of the Intertie was to energize the Intertie from the north as wel]as from the south. This is confirmed by the 'Operating Procedures Manual for the Anchorage-Fairbanks Intertie''supplied to the Operating Committee by APA.This operating capability must be retained. Therefore,when the SVS is to be used to energize the Intertie from the north,it must be capable of starting and operating under an islanded condition with GVEA at the minimum generation configuration. This minimum generation configuration is with ONLY the Healy Plant "on-line''and no other generation running on the GVEA system.GE's studies did not use this as the minimum generation configuration. 2.Under islanded conditions and with the GVEA system at a minimum generation configuration (Healy only),Healy SVS and Gold Hill SVS must be able to be started without causing adverse impact to the GVEA system.Presently the impact is excessive in the following areas: a)REA &GVEA flicker limits are exceeded (attached is a copy of the limits).From what we can tell from the current information,the -GHS SVS will cause over a 9%flicker and Healy SVS will cause a4O%flicker.A 3%flicker is the maximum allowed per REA &GVEA. GVEA will not allow any of its customers to exceed these prescribed flicker limits nor would GVEA operate the system intentionally to produce flickers in excess of this. »f./RBOLZEN VALLEY SLECTAIC AGSOCIATICN Wc. 4-5-85 Page 2 b)GVEA's absolute operating limitations on the transmission and generation buses range from .90 pu to 1.10 pu.The normal steady state limits are .95 pu to 1.05 pu.During starting, both the GHS and HLP SVS exceed this. c)Healy Plant is unable to absorb the MVAR requirements of the HLP or GHS SVS during starting while maintaining adequate system voltages. d)SVS induced harmonics appear to be excessive on the Healy machine to the extent that GE says that the Healy machine cannot be running during SVS start-up. e)The start-up of GHS or HLP SVS produces instantaneous MVAR flows on lines and equipment which approach or exceed fault level magnitudes and may trip out protective relay circuits. It is apparent that the GHS and HLP SVS start-up characteristics were not designed for a small system such as GVEA and do not meet REA guidelines or prudent utility practices. Under minimum generation conditions,GVEA's experience has shown that a 5 MVAR to 6 MVAR instantaneous impact on the system is about all we can withstand.Even this may not meet the flicker requirements. GVEA believes the SVS should be provided with control logic and be configured such that it is a soft start device in the normal operating mode. Please review SVS start,run and shut-down characteristics under the GVEA minimum generation system configuration with GVEA islanded and attempting to energize the Intertie from the north.Demonstrate that the impact on GVEA system is within acceptable limits as mentioned above and is consistent with REA guidelines and prudent utility practices. OnRobertOrr GVEA Operations Supt. cc:Mike Kelly Henri Dale Marvin Riddle John Huber Bob Heath -APA Tom Stahr -AMLEP Operating Committee Chairman Attachments Dispatch Training Subcommittee In Fairbanks -April 23,1985 The Dispatch Training Subcommittee met April 23,1985 at 9:00 A.M.at GVEA.Those attending were: John Aspenes UAF Bob Merritt UAF Marvin Riddle GVEA Allan Martin FMUS Ernie Jameison MEA = rime The dates were set for the Dispatcher Training at UAF.The first session was set for the period May 13th thru the 17th.This session will be the repeatoflastyear's session and the course content will not change. The second session will be the period June 3rd thru the 7th.This will be the advanced course. The University has stated they could only handle two sessions this year due. to other commitments. For the advanced session the utilities have defined a general course outline. This includes the following: SCADA -Discussion of types and methods of control. AGC -To include time error correction -frequency bias,ACE -how it isderived,how it is used. Rotating Machinery GT/GT Regenerative Units Combined Cycle Steam Hydro These are to concentrate on economic dispatch,response characteristic,start-up characteristics,restrictions and limitations on types of units. System Economic DispatchLossCalculationusingB matrix,on line load flows. Pool Coordination Power Transactions &Wheeling Power Determination of Operating Reserves Pool Planning &Operating Problems Stability John Aspenes will contact AML&P to determine if their consultant would be available to participate in the training. GVEA will allow use of their on-line load flow for demonstration purposes and course Instruction. The utilities will handle their own accomodations. The fee will be the same as last year -$750/person. The following utilities have committed to the listed numbers of people for each session: First Session Second Session MEA 3 MEA 2 FMUS rf FMUS 2 GVEA 3 GVEA A,AMLEP =7G)AMLeP =?&) CEA 0 CEA 0 Minutes submitted by:Marvin Riddle iW.'So isite &.L.wee OF PRUSSIA FA:E24,. a Se GENERAL @&ELECTRIC POWER SYSTEMS MANAGEMENT BUSINESS DEPARTMENT GENERAL ELECTRIC COMPANY @ CALL BOX 15 ®@ MALVERN,PENNSYLVANIA 19355-0715 ©(215)951-7000 May 3,1985 ALASKA POWER AUTHORITY Contract APA-83-C-0051 Reference:Morrison-Knudson Company.Inc. Letter to P.Sherman,GE Co.dated April 19,1985 S/N-M-K-51-0049 Cc.R.Parrish (loo we )Morrison-Knudson Company,Inc. 613 "D"Street Anchorage.Alaska 99501 Dear Charles: MK's April 19 response to GE's January 16 letter contends that the GE SVS at Healy is "not a complete system because it is not capable of start-up independent of the other Static Var Systems and required disconnection of the Healy generator from the system."Neither point is correct. 1.Our recommendation that either the Teeland or Gold Hill SVS be put in service prior to the Healy start was meant to apply only to the first start-up and operation of Healy during the SVC commissioning. 2.The Healy SVS does not require that the Healy generator(not a part of the SVS)be disconnected during: start-up.For the SVS start-up the Healy harmonic filters are not initially energized.This is standard P.02 MY.03 'ES 23:53 G.E, CR Parrish 2.(Continued) NG OF FPRUSSIG FR Gs F.03 GENERAL &ELECTRIC -2-May 3,1985 practice as well as a Contract requirement (Paragraph 6.3.2.12).Since the harmonic filters are off,the Healy generator will be subjected to the harmonics from the SVS during start-up and our January 16 letter therefore recommends the generator not be connected during this period to avoid possible damage to the generator. The SVS supplied by GE is complete and we have not deviated from the Specification., PSsemb cc:D Eberle L Miller JM Ladden WW Fink RJ Moran S Miske W Kaufman G Bosworth Sincerely, Phil Sherman Alaska Power Authority Commonwealth Associates,Inc. Jackson,MI EUSED,Schenectady,NY EUSD,Southfield,MI I8D,Anchorage,Alaska 29MenDDaeeae, ee Gs is CONTRACTORS ENGINEERS a.DEVELOPERSSPaahWiel"1:'MORRISON-KNUDSEN COMPANY,INC. -ANCHORAGE-FAIRBANKS INTERTIE 6130 STREET ANCHORAGE,ALASKA 99501 PHONE:(907)274-9566 May 6,1985 S/N-M-C-0647 Commonwealth Associates,Inc. 209 East Washington Avenue Jackson,MI 49201 Attention:Mr.Lytle Miller Subject:SVS START>UP AND OPERATION Reference:Alaska Power Authority Anchorage-Fairbanks Intertie Contract No.APA-83-C-0051 Static Var System Dear Sir: We have received a response from GE to our letter M-K-51-0049,April 19,1985.Both the M-K letter and GE response are attached for your easy reference. We ask that CAI review GE's position in light of their response to M-K-51-0049 and advise of CAI's position on these two matters. Your early response will be appreciated. Very truly yours, MORRISON-KNUDSEN COMPANY,INC. C.R.Parrish Construction Manager LCW/gki Attachment cc:D=R.Eberle --Alaska.Power:Authority '(w/att)*D.E.Chaffee -Morrison-Knudsen Co.,Inc.(w/att) .pet 5 44 CONTRACTORS 'GF Ace do!aENGINEERS. DEVELOPERS pat D.C fe »MORRISON-KNUDSEN COMPANY,INC.|RS1wll”ANCHORAGE FAIRBANKS INTERTIE z t eee ANCHORAGE ALASKA 99501 |G.L. PHONE.(907)274-9566 {O.7. |6.8. April 19,1985 S/N-M-K-51-0049 TS. }RM, ,[R.B.General Electric Company Tk1004West9thAvenuePKL. King of Prussia,PA 19406 Attention:Mr.Phillip Sherman Subject:STATIC VAR SYSTEM START-UP AND OPERATION Fite Coge Reference:Alaska Power Authority II-1-V.54Anchorage-Fairbanks Intertie (2-StfContractNo.APA-83-C-0051 (G Static Var System Gent lenen:Reply: GE's letter of January 16,1985,to Gilbert/Commonwealth imposed thefollowingtworestrictionsontheoperationoftheSVSatHealy: 1.The Healy SVS should be started with the Intertie connected back to_either Teeland or Goldhill and with the associated SVS (Teeland orGoldhil?)already in service. 2.During the start-up mode,the Healy generator should not beconnectedtotheIntertie. The effect of these restrictions is that the Healy generator must be removed from service to start the Healy SVS and energize the Intertie from the north. Contract APA-83-C-0051,page 3-2,paragraph 3.2.3,requires that each SVS: ."be complete with all power system equipment,components,controls,instrumentation,protection and any other ancillary equipment and devices necessary for complete installation and operation in -automatic,local manual and remote manual modes." The restrictions imposed by GE's January 16,.1985,letter are deviations from the contract requirements,in that the SVS System at Healy is not a "complete”system because it is not capable of start-up independent of the other Static Var systems and requires disconnection of the Healy from the system. generator Under page 6.2-2,paragraph 6.2.1,subparagraph 1.2 of the contract,GE mustmakeanychangesrequiredtoeffectcompletenessandfunctional/operational correctness of the Healy SVS. MIBE'SeeeNULEEN Coe ey ie General Electric Company|April 19,1985 S/N-M-K-51-0049 Page 2 of 2 GE is therefore directed to take the necessary corrective action to eliminate these operational restrictions and to provide a "complete"Static Var systematHealycomplyingwithallcontractrequirements. Please submit by May 3,1985,GE's schedule and plan for implementing the necessary modifications and/or additions to the Healy SVS. Very truly yours, HORRISON-KNUDSEN COMPANY,INCEE"NES C.R.Parrish Construction Manager LCW/gki cc:D.Eberle -Alaska Power Authority L.Miller -Commonwealth Associates,Inc.-Jackson,MI METERING /tomm, SCADA DESPATCH SUBCOMMITTEE MEETING MINUTES May 14,1985 The meeting was called to order by chairman Bob Orr at 1:20 P.M.in the Municipal Light &Power conference room,May 14,1985.Those present were: Bob Orr,Golden Valley Electric Association Afzal H Khan,Alaska Power Authority Dan Rice,Gilbert Commonwealth Pete Smithson,Municipal Light &Power Robert Day,Municipal Light &Power Jim Hall,Matanuska Eleectrie Association Larry Shalls,Chugach Eleectrie Association Vanee Cordell,Chugach Eleectrie Association Kevin D.Parsons,Chugach Electrie Association Marvin Riddle,Golden Valley Electric Association The meeting started out with Bob Day giving a report on the present status of Municipal Light &Power's vendor system control in reference to the implementation of the data link.The Municipal Light and Power SCADA system is expected to ship late June.That equipment will be as complete as possible as far as the intertie data link is concerned,with final testing to occur at a yet to be named date,depending on when Landis and Gyr is ready.Three options exist for the final testing: 1.Testing weight may be performed from ML&P,Anchorage to Landis and Gyr,San Jose. 2.SC will investigate the short term lease of an 1144 system to perform the testing and verification in California on a local basis. 3 A possibility exists that SC in California may have an 1144 system on the factory floor for another project and will be able to perform the testing and verification on that machine. That was followed up by Bob Orr giving a report on the status of the intertie from the Landis &Gyr/Golden Valley Electric perspective. The Chairman then called on Kevin Parsons from Chugach Electrie to give a report on Chugach's instrumentation and discussion ensued that indicated that Chugach is presently involved with writing adecnet@mulationtoprovideendnodeonly.This means that Chugach will be a radio link of the loop.Chugach expressed a desire to have a coordination meeting between the various vendors and Mr. Parsons to resolve and discuss any problems with their implementation. Page 1 of 4 It was indicated that Chugach has successfully added or successfully come up with a method to add a single DMR 11,but has a hardware problem in slot space availability for Chugach to add the second DMR 11 to provide for a loop network. Vance Cordell put the question of the APA/CEA reimbursement.That question was tabled for a later date and APA will be setting up a meeting with them to discuss that.ML&P noted that this modification from the specification was documented from the April 24,1984 doecu- ment produced by APA and the operating committee requires additional hardware for the consideration of CEA's radio system. Afzal Khan,APA,suggested that ML&P/CEA and APA have a meeting which will be held 9:00 A.M.Friday at ML&P to discuss the actual hardware requirements of the system as proposed.In the area of communications,there is a 9600 bod link established to CEA at their new dispatch center from ML&P's present computer location and it will be ready to start.This will provide CEA with a link to ML&P's SCADA system VSCRT so that they may look at the status of Teland's sub,Douglas substation and the ML&P/CEA intertie. It was noted that the modems need to be ordered or produced fromDuveomtoimplementthe9600beddatalinkbetweentheGoldenValley and ML&P.bend Voice communications is in and working well.It was noted that it would be desirable to get an extension into ML&P's switch so that Golden Valley can communicate with PlantI/Plant II during the off hours.In addition,this would provide Golden Valley the ability to dial Chugach through ML&P's local switch on a local phone eall, rather than the long distance.Bob Orr said he would speak to Duveom about getting the modems installed and also find out what will be required in order to implement the additional voice com- munication to provide an extension off ML&P's switch. Question from Bob Orr then about voice communications with MEA, Homer,ete.Jim Hall indicated that when the need becomes a reality then they will be installing those links as required. The present system as proposed by Landis &Gyr puts testing of the intertie data link in the October/November time frame.Due to this delay of the link,interim operating procedures will need to be developed by this committee or by other committees.The general intertie committee should be assigned some work duties to develope these procedures to one or more of the subcommittees. Page 2 of 4 Bob Orr and Marvin Riddle then gave a report on the testing start-up which occurred the end of April for approximately one week where the tie was operated.Power was suecessfully shipped both north and south.The line was picked up from the southern end,operated and then when attempting to pick up the line from the northern end, there was a failure in the SVS at Healy and as of yet the problem has not been corrected. Bob Orr noted that the voltages in Cantwell seemed to be 30-40% voltage flicker and this indicates a real control problem on the SVS system.In addition,the SVS metering PT's have a real problem as they are on the switchable bus.An additional set of PT's is needed to solve this problem.Bob Day reported on some control problems with the SVS system at Teland in that there is no feed back to indi- eate the present set point of the SVS system. Afzal Khan,APA,acknowledged receipt of the letter from ML&P con- eerning such and some discussion will be ensuing at the Friday meeting concerning this. It was discussed about the metering performance during the test and approximately 1.2 megawatt hour error over a 51.8 megawatt hours were sent north and 22.2 megawatts were sent south.This 1.2 megawatt error ineluded losses. The subcommittee directed the secretary to indicate to the general operating committee that a better and more substantial report on the status of the data link will be given next month,as the vendor meeting is seheduled for the 17th of May.This meeting was for- merly scheduled for the first part of May,but was postponed due to illness of one of the principals from Landis &Gyr. The question from the Chairman,then,was what the subcommittee viewed as the next important task for this committee to attack.It was noted that some spare bubble memories were needed.Jim Hall has some spares available,but in any case,each party who is going to be reading these meters needs to have some spare bubbles for swapping purposes.It was indicated that the bubble memories may not roll-over or be a circular file,as the instructions indicate to erase them before they are replaced into service.The implication is that they may loose data or trash data if they are allowed to overwrite previous information. The question then came up as to where the bubble translators are located.Apparently APA was to have two of these devices,but it is unknown as to their present whereabouts.Afzal Khan indicated that he will find out. Page 3 of 4 It was then indicated that the next topic for this committee would be to provide and review metering information and procedures.Dan Rice formulated a question on data collection,and how this ties into the dispatch committee.It will be necessary for the dispatch committee to formulate some forms and regulations or rules con- cerning data collection during the intertie so that this committee may take that data and verify that SCADA systems,metering systems are operating and indicating proper quantities.There may be a need of a joint dispatch/SCADA metering subcommittee in order to resolve these.This will not be too much of a problem as many of the per- sons on each committee are the same person from each utility. Dan Rice indicated the loss calculations are near to completion,but some parameters need to be verified before the load flows will be run. Bob Day motioned that the meeting be adjourned.The motion was seconded by Vance Cordell.The motion carried unanimously at 3:05 P.M. Respectfully submitted for the committee. Robert Day,Municipal Light &Power Page 4 of 4 DISPATCH SCHEDULING SUBCOMMITTEE May 14,1985 The meeting was held in the Municipal Light &Power conference room,1200 E.Ist Avenue,and convened at 9:00 A.M.The following persons were present at the meeting: Larry Walls,Chugach Electric Association Ray Dunean,Chugach Electrie Association Dan Rice,G-C Hank Nikkels,Municipal Light &Power Marvin Riddle,GVEA Pete Smithson,Municipal Light &Power 7)The interim method of filling,reconciling and controlling the intertie until all other required hardware is installed is asfollows:4 Municipal Light &Power will control tie line to CEA at Plant II,GVEA will control tie line to CEA at Healy. Starting tie line bias at GVEA 2.0 MW/.01Hz,ML&P. 5 .OMW/.01Hz ° , Accounting and reconciliation twice per day (on peak-off peak) KWH +Losses at Douglas =Net KWH _KWH_-_Losses at Healy Per Company Column-- Sum all in and all outs Net KWH at Douglas -Cantwell =Net Interchange.Inadvertant for GVEA is +Cantwell load For inadverdent account the established off peak times are 2100-0500.All other times are established as on peak. \ Losses will be established "os loss table provided by G-C/APATheschedulingwillbedoneHankNikkelsatML&P or Pete Smithson,ML&P,for the southern controller.The CEA schedule will be negotiated and verified by the purchasing utility.Prior to scheduling with the area controller.Marvin Riddle asked when ML&P power dispatching would be manned.Hank Nikkles said approximately one month,and scheduling would be with him or PeteuntiltransferredtoDispatching.Operation schedulingatGVEAwillbewithMarvinRiddle. Dispatch Scheduling Subcommittee May 19,1985 Page Two Intertie Billing Reconciliation: Out from Douglas 51,800 KWH In at Douglas 22,200 KWH(29,600)NET In at Healy Out at Healy 15,400 KWH In at Healy 25,400 KWH10,000 KWH NET * 18 ,400 CWS Load 28,400 -(GVEA)NET Difference 1,200 Each participant shall state in writing to the other participants who in their organization is authorized to establish schedules and prices for transactions. \ DISPATCH/SCHEDULING SUBCOMMITTEE MINUTES 9:00 A.M.-April 16,1985 AT MUNICIPAL LIGHT AND POWER Attendance:E.Jameson Matanuska Electric Association George Bowen Municipal Light &Power Ken Bradley Consultant Afzal H.Khan Alaska Power Authority Charles Parrish Morrison/Knuden Marvin Riddle Golden Valley Electric Association Larry Walls Chugach Electric Association Ray L.Duncan Chugach Electric Association Doug Hall Municipal Light &Power Mike Massin Municipal Light &Power Pete Smithson Municipal Light &Power Jerry Stevenson Municipal Light &Power John S.Cooley Municipal Light &Power Discussion with Morrison/Knudsen,APA and affected utilities detailed foundation of APA proposed start-up schedule and switching order. ML&P and CEA has concerns on how we handle billing for power used during start-up and special switching required to configure CEA's 138Kv International to Airport which presently networked at Port Worzonoff.If line relays all 138Kv system networked would relay. Discussed interim start-up for control CEA would regulate fre- quency,ML&P and GVEA tie line bias.ML&P uses Douglas Metering at tie line for system net.FMUS handled separately by GVEA. Need to address permanent solution for frequency control. Discussion on revenue metering calibration and sealing. Representive from each utility to witness when calibrated,sealed. 4 \ RESERVE/LOAD SHED SUBCOMMITTEE 1:00 P.M.-April 16,1985 AT MUNICIPAL LIGHT &POWER Attendance:Ray L.Duncan Larry Walls Ed Morris Howard Thacke Hank Nikkels Ken Bradley Doug Hall Marvin Riddle Bob Orr Larry Hembree Chugach Electric Association Chugach Electric Association Alaska Power Authority Alaska Power Authority Municipal Light &Power Consultant Municipal Light &Power Golden Valley Electric Association Golden Valley Electric Association Municipal Light &Power The Reserve/Load Shed Subcommittee met and discussed the defina- tion of Spinning and Operating Reserves as defined by Addendum #1 and Exhibit A of the Intertie Operating Agreement. It was a unanimous decision of the Subcommittee that the wording in B2.2.2(b)immediately supplying through action of automatic govenor controls.This is interpreted as saying the Spinning Reserve is that amount that is connected to the bus and ready to accept load by automatic governor controls (machine droop)or a higher level of control. B-2.2.2 B-2.2. Generating unit capability for Operating Reservesshallbedeterminedbythefollowingcriteria: a.It shall not be less than the load on the machine at any particular time nor greaterthan(b)below.<b.It shall not exceed that maximum amount of hslead(IM7)that the unit is capable of [ahacontinuouslysupplyingforatwo-hour period,/AGeorimmediatelysupplyingthroughaction-ablautomaticgovernor.controls. a 7 Droge qeiensneThecriteriaspecifiedinthissectionmaybemodifiedcrchangedbytheOperatingCommittee. Section B-2.3 Utility Participent's Allocation of Operating B-2.3.1 Section B-2.4 B-2.4 1 Reserves The Operating Reserve Obligation of a UtilityParticipantshallbethatpercentageoftheTotal Operating Reserve Obdligation determined by the Operating Committee in accordance with:the following fornula based on the capability oflargestgeneratingunitcontingencyincperation at each Utility Participant._ B-2.3.1.1 Individual Utility Participant ReserveAllocationFormula: IOR =TOR x Us/Ut Operating Reserve Calculaticn System Spinning Reserve shall be calculated at anygiveninstantasthedifferencehetweenthesumofthenetcapabilityofallgeneratingunitsonlineintherespectivesystemandtheintegratedSvstemsDemandofthesvsteminvolved. Addendum No.1 -32 of 7 IOR =Individual Utility Participant Operating Reserve Requirement TOR=Total Operating ReserveRequirement Us =4 Utility Participant largest .on-line generation unit capability ; Ut =Sum of each Utility Participant' a -Sone ee ee m+-=ts -- Wem ae ee Anchorage "Fairbanks Intertie Uperating Committee MINUTES THURSDAY,MARCH 21,1985 (At Fairbanks) ATTENDANCE:Mike Massin Municipal Light &Power Hank Nikkels Municipal Light &Power Jim Hall Matanuska Electric Association Robert Orr Golden Valley Electric Association Ed Morris Alaska Power Authority Walt Lawson Matanuska Electric Association Dan Rice Gilbert-Commonwealth John Marshall Chugach Electric Association Afzal H.Khan Alaska Power Authority Howard Thacke Alaska Power Authority Marvin Riddle Golden Valley Electric Association Sam Matthews Homer Electric Association Larry Colp Fairbanks Municipal Utilities System John Aspnes*University of Alaska-Fairbanks *Joined meeting in progress. The meeting was called to order by Chairman Robert Orr at 9:20 in the Fairbanks Municipal Utilities System Conference Room. Sam Matthews motioned that the minutes be adopted as written.Bob Orr seconded the motion.The motion was approved unanimously. Sam Matthews then motioned for the agenda to be adopted as pre- pared.John Marshall seconded the motion.The motion was approved unanimously. Under Committee Correspondence and Reports,Bob Orr noted that Golden Valley Electric Association had sent the Alaska Power Authority a letter indicating that the GVEA SCADA system is complete to the extent that it will function as the Northern Area Controller.(See attached).Bob also reported that MunicipalLight&Power had sent a letter to Chugach Electric Association regarding CEA SCADA information required for intertied operation and that Chugach Electric Association had responded to the ML&P letter.(See attached letters). Sam Matthews then reported on the March 20,1985 joint meeting between the Reliability/Criteria and Dispatch/Scheduling Subcommittees which took place at Golden Valley Electric Association.He reported that Gilbert-Commonwealth had furnished the group with the latest updated "Alaska Railbelt Interconnected Utilities Data Book"(two volumes)and that Gilbert-Commonwealth had also furnished the "Alaska Railbelt Loadshedding for Spinning Reserve"report.(Sam furnished the Operating Committee with a set of minutes which are attached). AFIOC Minutes March 21,1985 Page 2 Bob Orr noted,for the record,that Golden Valley Electric Association intends to follow steps 1 through 10 in the Gilbert- Commonwealth "Alaska Railbelt Loadshedding for Spinning Reserves" handout furnished to the Reliability Subcommittee on March 20, 1985, Marvin Riddle then gave a report on the separate meeting held by the Dispatch/Scheduling Subcommittee.This meeting was also held on March 20,1985 at Golden Valley Electric Association.(Marvin also furnished the Operating Committee with a set of minutes which are attached).-He noted that the subcommittee had reviewed load levels and system configurations.He reported that the subcommit- tee had developed a loss determination system configuration user table for discussion by the full Operating Committee. Afzal Khan furnished an Intertie status update and provided the Operating Committee with a start-up and commissioning schedule. (See attached).He reported that the harmonic testing to take place at the Healy Generating Station had been delayed for at least a week from the time frame indicated in this schedule.Bob Orr noted that Golden Valley Electric Association was still con- cerned about the SVS bus modifications.Bob also requested that the Power Authority provide an updated SVS modification schedule. Khan reported that the Gold Hill transformer has now arrived at the St.Louis location for repairs.Dan Rice noted that the Intertie Operating Manual is still in draft form pending a resolu- tion of the Healy SVS operating problem.Khan reported that the Alaska Power Authority is looking into the SFg problem with the Westinghouse breakers.Several members of the Operating Committee expressed a strong concern about the application of SF¢type cir- cuit breakers in the Alaska environment.Problems occurring , include:SFg leaks,SFg low pressure problems due to cold cli- mate and tripping of the circuit breakers due to low pressure relaying.Khan also reported that there have been some SCADA microwave link changes at the southern end of the intertie project which involve Municipal Light &Power and Chugach Electric Association.He reported that the SVS switch gear modifications at the Teeland and Healy substations are complete.He noted that the SVS bus at Teeland,Healy and Gold Hill substations is intended to be raised,but has not taken place as of this time. Mike Massin requested that the Alaska Power Authority schedule a south end start-up meeting for the week of March 25,1985.Afzal Khan will contact the southern end utilities to arrange for a meeting. Turning to Visitors Comments and Business,Dr.John Aspnes from the University of Alaska-Fairbanks was in attendance and provided comments regarding the Dynamic Stability Study.He noted that they have now developed a working model and they are ready to AFIOC Minutes March 21,1985 Page 3 begin running some specific cases.John noted that Harry Beck is nearing completion on his Masters thesis.John also thanked the Operating Committee for their support.Bob Orr then asked Dr. Aspnes about the University of Alaska-Fairbanks aurora borealis study and the installation of neutral current instrument transfor- mers.It was noted that these instrument transformers have been installed at Teeland,Healy and Gold Hill substations.John noted that the University of Alaska-Fairbanks is going to be looking at the frequency spectrum of the neutral currents.Mike Massin then asked if a second round of dispatcher training seminars would be held at the University of Alaska-Fairbanks during the late spring of 1985.This would be the.same type of dispatcher training which took place in the late spring of 1984.Bob Orr and Hank Nikkels both expressed to Dr.Aspnes a desire to continue the training seminars.Dr.Aspnes indicated that he and Mr.Robert Merritt will not be able to make as lengthy a time commitment in 1985 as they did in 1984.After Dr.Aspnes left the meeting,the Operating Committee briefly discussed the use of training tapes for dispatcher training. The Operating Committee had no Old Business to conduct at today's meeting. Turning to New Business,the Operating Committee recessed into work session at 11:00 a.m.The Operating Committee then began a lengthy discussion on the application of loss factors as they apply to the transfer of energy on the Intertie and the associated intertie wheeling circuitry.The group felt that the Alaska Power Authority should direct Gilbert-Commonwealth to develop a line segment loss application table or tables to a resolution of whole "megawatts".The group agreed that loss applications also be determined for the University Substation to Soldotna line segment owned by Chugach Electric Association. The Operating Committee then recessed for a lunch break at 12:00 p.m.and reconvened again at 1:30 p.m. Continuing in work session,the Operating Committee then began a discussion on spinning reserve requirements as they relate to the use of automatic generation control.Mike Massin noted for the record that the Reliability/Criteria Subcommittee minutes of March 20,1984,which indicate that "concensus was that all units on line are required to have AGC",is interpreted by ML&P to be a goal and is not an initial intertie start-up requirement.The group then proceded to discuss the requirement that the Operating Committee will have to make an interpretation of the automatic generation control/spinning reserve requirement.Hank Nikkels noted for the record that ML&P does not currently feel that the Intertie Contract defines the automatic generation control/spinning reserve requirement. AFIOC Minutes March 21,1985 Page 4 Turning to the "Alaska Railbelt Interconnected Electric System Data Book",Hank Nikkels noted that the Machine/Ratings infor- mation is still old,containing raw data and not the Machine/Rating Book information prepared by the Machine/Ratings Subcommittee. Chairman Orr indicated that when the Committee reconvenes in full session,that he would recommend that the Reserves/Loadshed Subcommittee review reserve requirements and that he would further make a recommendation that the SCADA/Metering/Communications Subcommittee meet to review the status of the intertie data link. The Operating Committee reconvened into full session and proceded to elect new Operating Committee officers for 1985.After some discussion,in which it was pointed out that the Operating Committee had informally agreed early on that officers would serve no more than two consecutive terms in any specific position,the Committee proceded to nominate and elect the officers. Sam Matthews nominated Mike Massin from Municipal Light &Power for Operating Committee Chairman and A.Khan seconded the motion. Having no other motions for Chairman,Chairman Orr closed the nominations for new Operating Committee Chairman and the Operating Committee voted unanimously for the selection of Mike Massin as the 1985 Operating Committee Chairman.Turning to Operating Committee Vice-Chairman,Sam Matthews nominated Bob Orr from Golden Valley Electric Association for Vice-Chairman and John Marshall seconded the motion.Larry Colp then nominated A.Khan from the Alaska Power Authority for Vice-Chairman and Bob Orr seconded that motion.Larry Colp then withdrew his nomination of A.Khan for Vice-Chairman and with no further nominations,the nominations were closed.The Operating Committee then unanimously selected Robert Orr for Vice-Chairman for 1985.Turning to Operating Committee Secretary,A.Khan nominated John Marshall from Chugach Electric Association to be Secretary and Sam Matthews seconded the motion.Bob Orr then nominated A.Khan from the Alaska Power Authority to be Operating Committee Secretary and Larry Colp seconded the motion.The nominations were then closed and the Committee voted five votes for A.Khan to be Secretary and one vote for John Marshall to be Secretary.A.Khan,by a majority vote,will be the Operating Committee Secretary for 1985. Effective at the beginning of the next full Operating Committee meeting in April,the new slate of officers will begin their new duties. Turning to formal action of the Operating Committee,Chairman Orr motioned that the Operating Committee direct the Alaska Power Authority to provide loss tables for determination of line segment losses and scheduling values for interchange of energy between the various participants.Mike Massin seconded the motion.The motion was carried unanimously. AFIOC Minutes March 21,1985 Page 5 Turning to Subcommittee assignments,Chairman Orr then directed the DISPATCHER/TRAINING SUBCOMMITTEE TO MEET AT 9:00 A.M.ON APRIL 11,1985 AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION OPERATIONS DISPATCHER TRAINING ROOM for the purpose of reviewing the 1985 Dispatcher Training Schedule.Specifically,they should review the UAF Dispatcher Training Program.Mr.John Aspnes and Mr.Robert Merritt from the University of Alaska-Fairbanks will be in atten- dance at this meeting. Chairman Orr then directed the DISPATCH/SCHEDULING SUBCOMMITTEE TO MEET AT 9:00 A.M.ON TUESDAY,APRIL 16,1985 AT THE MUNICIPAL LIGAT AND POWER ENGINEERING CONFERENCE ROOM For the purpose of working on schedules,accounting formats and procedures for transfer of energy on the interconnected utility systems. Chairman Orr further directed that the RESERVES/LOADSHED SUBCOMMITTEE MEET AT 1:00 P.M.ON APRIL 16,1985 AT THE MUNICIPAL LIGHT &POWER ENGINEERING CONFERENCE ROOM for the purpose of reviewing spinning reserve requirements and how they can be met on an interim basis as well as a long term basis and make written recommendations to the full Operating Committee.Finally, Chairman Orr directed the SCADA/METERING/COMMUNICATIONS SUBCOMMITTEE TO MEET BEFORE THE NEXT FULL OPERATING COMMITTEE MEETING IN APRIL for the purpose of reviewing the current status of the Anchorage-Fairbanks intertie data link and particularly in the area of vendors,software and operation and furnish the full Operating Committee with a written report on the meeting. AS A REMINDER:THE SUBCOMMITTEE CHAIRMEN ARE ADVISED THAT THEY ARE TO CONTACT AND NOTIFY THEIR RESPECTIVE MEMBERS OF SPECIFIC MEETING DAYS AND TIMES. The Operating Committee then proceded to set the agenda for the next full Operating Committee meeting.THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE-FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE AT 9:00 A.M.ON WEDNESDAY,APRIL 17,1985 IN THE MAIN CONFERENCE ROOM OF MUNICIPAL LIGHT &POWER AT 1200 EAST FIRST AVENUE,ANCHORAGE,ALASKA. Larry Colp then motioned for the meeting to adjourn.Marvin Riddle seconded the motion.The Operating Committee then approved the motion to adjourn at 3:15 P.M. Respectfully submitted, Miké Massin-Secretary Anchorage-Fairbanks Intertie Operating Committee MEM/csn a?AFIOC Minutes March 21,1985 Page 6 Attachments:GVEA letter to Alaska Power Authority Municipal Light &Power letter to Chugach Electric Association Chugach Electric Association letter to Municipal Light &Power Minutes from the March 20,1985 Reliability/Criteria and Dispatch/Scheduling Joint Subcommittee meeting Distribution listing for recipients of the Alaska Railbelt Interconnected Electric Systems Data Book Minutes from the March 20,1985 Dispatch/Scheduling Subcommittee meeting Intertie Start-up and Commissioning Schedule April Operating Committee Agenda 4 Anchorage "Fairbanks $Intertie O Uperating Committee -AGENDA- Wednesday,April 17,1985 Begin at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A.SCADA/Metering/Communications Subcommittee B.Dispatcher/Training Subcommittee C.Dispatch/Scheduling Subcommittee D.Reserves/Loadshed Subcommittee E.Intertie Status Update (A.P.A.) IV.Visitor comments related to items on agendaOV.Old business VI.New business A.Recess and work session B.SCADA/Metering/Communications C.Dispatcher/Training De Dispatch/Scheduling E.Reserves/Loadshed F.Other VII.Formal Operating Committee actions/recommendations VIII.Subcommittee assignments IX.Set agenda for next meeting X.Adjournment Adjourn by 3:30 P.M. pO Meeting location:Municipal Light and PowerMainConferenceRoom 1200 East First Avenue Anchorage,Alaska (907)279-7671 tvo SFTRUE --_ a '\Maiesy wo? on :wy)1 IY%,,gre ihe fa!\Di ison SOLOEN VALLEY ELECTRIC ASSOCIATION INC.Box 1249,Fairbanks,Alaska S9707 Phone SO7-452-1151 Mareh 8,1985 Mr.Dave Eberle Alaska Power Authority 334 W.Sth Avenue Anchorage,Alaska 99501 Dear Dave: ) ) This letter is to inform you that GVEA's SCADA System is completed to the extent that it will function as the Northern Area Controller.The intertie-related control analog andindicationpointsareinplaceandoperational.All GVEA generating units are under AGC control and the programs are fully operational to maintain interconnected operations. We are anxious and able to now begin receiving economy energy from Anchorage.Please expedite completion of those facilities required to implement operation.Please call meOifIeanbeofassistance. Best regards, ith §bqRobertOrr Operations Superintendent xe:Bob Heath,APA Exec.Dir. Tom Stahr,AMLXP Bob Martin,CEA . Mike Kelly,GVEA Operating Committee 6 O F:4 ']Li i & | W a ”saEMunicipalLight&Power <4.af 4 yan |O X oy 1200 EAST FIRST AVENUE -ANCHORAGE.ALASKA 99501-1685 Since 1932, 'Se” TELEPHONE (907)279-7671TonyKnowles, Mayor y 8vadfitA'owe aeoa8 7)Mr.Eric Haemer a aeDirector,Production &Major Porjects HEChugachElectricAssociation”- P.0.Box 6300 Anchorage,Alaska 99502 Subject:CEA Information for Intertied Operation Dear Mr.Haemer: CEA requested that ML&P investigate a direct SCADA data link with CEA, because it was not possible for CEA to participate with the Anchorage- Fairbanks Intertie DEC/NET protocol that was established April 24,1984. After discussion with our SCADA equipment supplier (SCI),it was felt that the implementation of such a data link would delay our current SCADA pro- Zz ject schedule by tying up our key personnel and delaying equipment and software finalization.In addition,the data link would probably not pro-O vide satisfactory security and much of the required (or requested)datafromCEAwouldstillrequiremanualentry. We believe that the following alternative could be implemented quickly and be cost effective.It would meet the intertie data requirements,and would allow CEA to expand their system to utilize DEC/NET when your equip- ment is up-dated with no major investment in specially devised systems or software. 1. ML&P would devert three of its SCADA RTU's that are currently on order to be mounted at CEA's generating facilities (Beluga,Bernice andInternationalStations).There is already a unit at UniversitySubstation.No controls would be implemented through these units,buttheywouldmonitorgeneratorbreakerstatus,load at each unit,vars at each unit,and the position of critical breakers (to the intertie) at the stations.CEA would bear the cost of the units on a negotiatedleasebasis.The installation of the RTU's would be done by acontractormutuallyacceptabletoML&P and CEA.The cost of the installation would atso be borne by CEA or it could be a part of theequipmentleaseprice. 2.CEA would provide tranducers outputs,pulses,contacts,and other required signals to an interface panel (dual terminal strip form of interconnection).The intent would be to utilize CEA's existing transducers into parallel operation in order to simplify and minimizetheinstallationeffort. PROVIDE FOR TOMORROW,SAVE ENERGY TODAY, Mr.Eric Haemer Page 2 February 27,1985 CC: CEA would be responsible for the communications system.It was Suggested that the existing CEA microwave system has adequate capacity to accomplish good communications. Modems would be provided as part of the RTU's by ML&P. As part of the leased equipment,ML&P would provide a CRT and a printer at the CEA dispatch center.This equipment would make al] pertinent informtion available to CEA at their dispatch center.It would also be easy to implement a dedicated line using a fixed format to automatically download intertie data from ML&P's SCADA to CEA's computer. Maintenance and calibration of the equipment would be reimbursed directly by CEA. If you are interested,please notify me so a meeting can be set up. ;Yours truly, Hank Nikkels Generation Manager Thomas R.Stahr Mike Massin Robert Day Dan Rice,Gilbert Commonwealth Bob Orr,Chairmanof the Intertie Committee Robert Martin,Manager CEA O sabehtetherokeeenn __LS/ljm __._..- a) ELECTRIC ASSOCIATION.INC.7 »»MINNESOTA DRIVE ¢POUCH 6300 e ANCHORAGE.ALASKA 99502-0300 *PHONE 907-563-7494,TELEX:CHUGACH AHG (090)25 265 March 7,1985 RECE/VED aa ,FoRMr.Hank Nikkels QAyA SS i ounepes -\Generation Manager pooM hye Municipal Light and Power aout lot 1200 East First Avenue eecrne as tT DIsTRtey Anchorage,Ak 99501-1685 OPERATIONS DEPT. Subject:Your letter dated February 27,1985 RE:Anchorage-Fairbanks Intertie Dear Mr.Nikkels: Thank vou for your letter of February 27,1985 but this lettermusthavebeensenttoChugachElectricbymistake. As discussed and proposed at the February 5,1985 meeting, Chugach has the capability of emulating DECnet. Item 5 of your letter reflects our proposal of September 28,1984(copy attached)which was found to be unacceptable by the AlaskaPowerAuthority.Based on that determination,Chugach is proceeding with the development of a DECnet emulation. Apparently a misunderstanding still exists and I would recommendameetingtoresolvethisissueandformalizeimplementation responsibility. If you wish to discuss this further,I can be contacted at 564-0751. Sincerely, Sire fe SV Eine Linda Stewart SCADA Project Manager cc:Thomas R.Stahr Mike Massin Robert Day Dan Rice,Gilbert Commonwealth Bob Orr,Chairman of the Intertie Committee Bob Martin,CEA Manager Tom Kolasinski,Assistant Manager,CEA Eric Haemer,Director,Production and Major Projects,CEA Attachment Meeting Minutes ly RELIABILITY/CRITERIA SUBCOMMITTEE & DISPATCH SCHEDULING March 20,1985 -1:30 P.M.-GVEA Those in attendance were: Sam Matthews HEA/AEGT Ray Duncan CEA Robert Day AMLEP Larry Colp FMUS Jim Hall MEA Bob Orr GVEA John Marshall CEA Marvin Riddle GVEA Harry Beck -UofA Walt Lawson MEA Dan Rice G/C Ed Morris APA Howard Thacke APA Steve Haagenson GVEA Afzal Khan APA Dan Rice passed out numbered sets of the ''Alaska Railbelt Interconnected Electric System Data Book.''List of numbers and assigned utilities will be available. There was discussion of methods for updating.Concensus seemed to be that it should be the responsibility of the Reliability/Criteria Subcommittee to gather the information on an annual basis by March tst.G/C will provide computer tape and reproducibles of drawings and one-lines so we can add future information and changes.Subcommittee will store them for future use and transmit to Chairman.Disposition will be from there. Dan passed out ''Alaska Railbelt Load Shedding for Spinning Reserve.''Extensivediscussionofresultsofstudyandhowtogetbackto60HZaftergenerationloss.Concensus was that all units on-line are required to have AGC.It was noted that Exhibit 8,sheet 2 had errors.GVEA requested any available information on individual machine power output.Motion by Matthews,second by Haagenson that Subcommittee accept report pending receipt of corrected information on Exhibit 8 and any available machine power output dates. Motion carried unanimous. Discussion of loss tables required for start-up.Dispatch Scheduling Subcommittee will decide format and G/C will do them per prior promiseofMikeYerkes(APA). Meeting adjourned at 4:10 P.M. On March 20,1985 at the Reliability/Criteria Subcommittee and Dispatch Scheduling meeting copies of ''Alaska Railbelt Interconnected Electric System Data Book''were distributed as follows:WONAUEWNHEA -Sam Matthews CEA -Marshal} CEA -Duncan CEA -Martin GVEA -Orr GVEA -Haagenson GVEA -" AML&P -Day AML&P -'3 AML&P -"! FMUS -Colp FMUS -'! U of A -Beck MEA -Hall APA -Kahn APA -' G/C -Rice /pUi :_z aonpsTuiperdDISPATCHSCHEDULINGSUBCOMMITTEEMEETING$ GVEA,Fairbanks March 20,1985 Those in attendance were:Bob Day AMLP Marvin Riddle GVEA Ray Duncan CEA The subcommittee recommends the following format and condition be used in determining losses during startup of the Intertie until on-line load flows are available.Further recommend this format be submitted to A.P.A.for them to provide,using studies they have available. System load levels based on 1985 forecasted peaks: 1)40%-light load 2)75%-normal load 3)100%-peak loads System Confiqurations SOUTHERN SYSTEM 1)Teeland -open or closed 2)Eklutna N -open or closed 3)University 115KV tie to AMLP -open or closed "=with CEA supplying power (230 KV closed)(230 KV open) _7 with AMLP supplying power -with both supplying power NORTHERN SYSTEM 1)1-69 KV circuit GH-ZNS in service 2)2-69 KV circuits GH-ZNS in service with or without Healy generation Following tables are based on switching configuration -1 page table per configuration includes columns for system load then losses. (SYSTEM CONFIGURATION) Gen Mix System Load AMLP |CEA 40 75 100 CEA MLEP CEA ML&EP {CEA MLEP Tie |CEA Tie]CEA Tie |CEA 0 100 10 90 %of Delivery 20 80 30 70 ko 60 50 50 60 40 70 30 80 20 90 10 100 0 %of Delivery PA MORRISON KNUDSEN ATTS SHOWN IN HEADER ARE MONDAYS INTERTIE START-UP AND COMMISSIONING SCHEDULE UPLATED 3afes For 'iyb/sTpe ipuier vT€> SCHEDULE BASED ON SIX DAY WORK WEEK MARCH JUNE 11 18 25 22 29 3 10 17 ONPEXFEGR TOCFATILE TERNE POVOA LE KEK AME |vig)a i wosh erin 9 cr punts manor:Se ae On eTteed OnenerCORNER SEES "etSeGA Sie a EE eels by 55Fe)=!Meh 2em le vie:MSE XENUENST.LOUIS FIINEERNMES D5" o =ose saa MONE ONTO)FAG a{+ EEA DSTILE KOWCOHIENT.#7} LNOQ METASEM SLY fo TIT ech =TE ux a =eer INS TILL RIGHSE OWL LSELONDEGERABOELENOBSitis>aeEK Neha PERFORM svi orboruké esradeL)Hed Op fe CT Sk HEN TS beep coms<<mr_(8S)PECK Corara LpuKLi(GVEA beexADDfonRAOearwreryert, -acd som et < r amen,rams ann peweaz:4s eocoor 49] 9 rs)CHEE AE LORD LNG ENE 5 TER iL:LO i bie SCADA Pop..TQaea) LD teiSSERATE LO CHESH (OKA-LIIC¥A)1!omens,ae comet.- .Amoniey slr gus SePOINT |AECKla)CHELKANT BGR > >A ENERGIZE 4NGR N INSTI LD hy¢BOUABLETES E37 gjSRaiteinA?RIB .y L (SE)IER TLOY TEST.$i'u PETE Cond BEAM -apaerjacac GE os aidan Anchorage "Fairbanks Intertie Uperating Lommittee ATTENDANCE: Thursday,February 14,1985 (At Anchorage) Mike Massin James Hall Sam Matthews Afzal H.Kahn Ed Morris John Marshall Woody Baker Marvin Riddle Municipal Light &Power Matanuska Electric Association Homer Electric Association Alaska Power Authority* Alaska Power Authority* Chugach Electric Association Golden Valley Electric Association Golden Valley Electric Association Dan Rice Gilbert-Commonwealth* F.S.Prabhakara Gilbert-Commonwealth* Larry Colp Fairbanks Municipal Utility System Ram Krishna Steven Arnold Howard Whitney Lee Warnack Duane Chaffee Charles Parrish Larry Hembree Morrison-Knudsen* Gilbert-Commonwealth* Gilbert-Commonwealth* Morrison-Knudsen* Morrison-Knudsen* Morrison-Knudsen* Municipal Light &Power* Robert Day Municipal Light &Power* Hank Nikkels Municipal Light &Power* Tim Fink General Electric* Stan Miske General Electric* Jib Bosworth General Electric* Bob Bain General Electric* *Joined meeting in progress The meeting was called to order by Vice-Chairman John Marshall at 9:15 a.m.in the Municipal Light &Power conference room. Marvin Riddle motioned that the minutes be adopted as written. Sam Matthews seconded the motion;the motion was approved unanimously. Mike Massin motioned for the agenda to be modified to allow for the General Electric/Gilbert-Commonwealth SVS presentation to be made under the Committee Correspondence and Reports portion of the meeting.Additionally,Mike motioned for the Committee to allow Dr.Prabhakara to give his Case Study presentation under Item E of the New Business portion of the meeting.Marvin Riddle seconded the motion;the motion was approved unanimously. Under Committee Correspondence and Reports,Marvin Riddle reported on the February 5,1985 SCADA/Metering/Communications Subcommittee meeting and furnished a set of minutes from the meeting (see attached).Marvin noted,for the record,that Gilbert-Commonwealth is firmly committed at this time to pursue the Anchorage/Fairbanks a February 14,1985 AFIOC Minutes Page 2 Intertie Data Link Requirements dated December 31,1984 and as adopted by the Operating Committee on January ,1985.Mike Massin then also noted,for the record,that Municipal Light and Power is taking the same position as Golden Valley Electric Association regarding firm pursuit of the Anchorage/Fairbanks Intertie Data Line Requirements.Mike and Marvin also noted that Municipal Light &Power and Golden Valley Electric Association intend to pursue the joint Functional Specification for the Anchorage/Fairbanks Intertie which was prepared by representatives of Municipal Light &Power,Golden Valley Electric Association and their respective SCADA vendors.Marvin Riddle also furnished the Committee with a copy of the Functional Specification for the Anchorage/Fairbanks Intertie (see attached). It was noted that Municipal Light &Power was traveling to Fairbanks on February 15,1985 to discuss initial operation and coordination of the Intertie with Golden Valley Electric Association. Sam Matthews then reported on the Reliability/Criteria Subcommittee meeting which was held at Municipal Light &Power on February 12,1985.He reported on Dr.Prabhakara's (Gilbert-Commonwealth)presentation on the Intertie Case Studies which were recommended by the Operating Committee.Sam also noted that Chugach Electric Association had given the Reliability/ Criteria Subcommittee a status update on their intended 230KV upgrading of the Pt.McKenzie to Teeland transmission line and the Teeland Substation upgrading.Sam also reported that Gilbert- Commonwealth is finalizing the Alaska Railbelt Interconnected Electric System Data Book (two volumes).He noted that the Operating Committee at some point will have to make a decision as to who will be responsible and what the methodology will be for Maintaining the updating required for this data book in the future. Turning to Dispatch/Scheduling,Marvin Riddle noted that with no on-line load flow capability initially,that the utilities will have to agree on a method for determining system losses during this initial time period.He noted that this subject had been discussed during the joint subcommittee meeting between Dispatch/ Scheduling and SCADA/Metering/Communications. Turning to a status report on the Anchorage/Fairbanks Intertie project,Mr.Afzal Kahn from the Alaska Power Authority intro- ducted Mr.Ed Morris who will be the new Alaska Power Authority Planning Director.Kahn reported that the three SVS locations had not had a functional checkout as of this date.He also reported that the Healy and Teeland SVS systems will require some bus modi- fication outside of the control buildings.Both the Alaska Power Authority and Golden Valley Electric Association reported that they have experienced leaks with the SF¢138KV circuit breakers >ere 'a Oo eye et ee .. betes .Pua '"nee Meee S oe oo Beye meggeer cowl RadeneategfeaRgmegty,LesteaCeeSEaonceaoeallViperayefey February 14,1985 AFIOC Minutes Page 3 at Teeland and Healy Substations.John Marshall noted that Chugach Electric Association anticipated having the Teeland switchyard reconstruction completed by October 1,1985 but the completion date he indicated is still preliminary and very ten- tative.Duane Chaffee from Morrison-Knudsen also provided a brief report on the inspection and testing of the transmission line portionoftheIntertieproject. As this point in the meeting,Acting Chairman Marshall turned the meeting over to Gilbert-Commonwealth,Morrison-Knudsen and General Electric to make a presentation and provide discussion on the Static Var Systems for the Teeland,Healy and Gold Hill Substations. At this point,Mike Massin also requested that Morrison-Knudsen take notes of the presentation and furnish them to him prior to the distribution of the minutes for this Operating Committee meeting.(These notes from Morrison-Knudsen are attached to these minutes.)Following the presentation and discussion by Gilbert-Commonwealth,Morrison-Knudsen and General Electric,the Operating Committee adjourned for lunch at 11:45 a.m. The Operating Committee reconvened at 1:30 p.m.and continued with the regular portion of the meeting. Other than the SVS presentation made during the morning session of the meeting,there were no visitors present during the afternoon portion of the meeting. The Operating Committee had no Old Business to conduct at today's meeting. Turning to New Business,the Operating Committee recessed into aworksessionat1:40 p.m. The Operating Committee then beganto a discussion on the presen-tation made by General Electric on the three SVS systems for the Intertie.Marvin Riddle expressed in strong terms that GoldenValleyElectricAssociationdoesnotfeelthathavingtotake the Healy generation off-line prior to Healy SVS start-up is accep- table.Sam Matthews questioned whether the SVS systems being pro- vided met specification.John Marshall referred the question to Dr.Prabhakara.Dr.Prabhakara then provided the Operating Committee with a historical background of the matter.There was a lot of discussion on whether the SVS met the Alaska Power Authority specification.The concensus of the Operating Committee discussion seemed to indicate surprise that General Electric didn't understand or take into account that the Healy generation is base-load generation.The group also discussed at length their concerns about mitigating the effects of harmonics during SVS energizations.The concensus of the group appeared to be that the Operating Committee should not be a party to any acceptance of an 2,operating limitation (ie.,Healy off-line to energize SVS at HealyontheAnchorage/Fairbanks Intertie).ves dtd$7;February 14,1985AFIOCMinutes-Bo Page 4 There was no additional dicussion regarding SCADA/Metering/ Communications or Dispatch/Scheduling. Turning to Reliability/Criteria matters,John Marshall then turned the meeting over to Dr.Prabhakara to discuss the Alaska Railbelt Utilities Operating Reserves Verification report done by Gilbert- Commonwealth.i:Dr.Prabhakara noted that a final report in this matter will be issued in approximately two weeks.He also reported that:ithe final printed Alaska Railbelt InterconnectedElectricSystemDataBooks(two volumes)will be made available to the Reliability/Criteéria Subcommittee at its next meeting which is to occur in Fairbanks.At 3:40 p.m.,the Operating Committee came"out of:Work:Séssion'and proceeded into the formal OperatingCommitteeAction/Recommendations portion of the meeting. Sam Matthews motioned for the Dispatch/Scheduling Subcommittee to be assignedtheresponsibility of making a determination and pre-paring a methodology for identifying losses on the Intertie during the initial period of operation when on-line load flow capability will not be available.The work of the Dispatch/Scheduling Subcommittee,in making these loss determinations,is to be limited to the Intertie portion of the Anchorage/Fairbankstransmissiononly.7?Sam additionally included in his motion arequestfortheDispatch/Scheduling Subcommittee to review and utilize the'load.flow studies previously completed by Gilbert- Commonwealth.Marvin Riddle seconded the motion;the motion wasapprovedunanimously”. Sam.Matthews"then.motioned for the Operating Committee to request of the Alaska Power Authority that they determine whether or not the General Electric_furnished SVS systems meet the specification they were bid under.Additionally,he requested that the Operating Committee'require that the Alaska Power Authority coor- dinate in a joint effort with Golden Valley Electric Association to perform fifth and:seventh harmonic measurements including magnitude at the Healy location under the four conditions listed:one.Healy-on with no Usibelli coal operation underway. -Healy-on with the Usibelli drag line operating only. -Healy-on with the Usibelli drag line and peak shaver in operation. -Healy-on with just the Usibelli peak shave in operation.meWNFPAs a point of clarification,the request of the motion by Mr. Matthews regarding the APA determination of 'the GE SVS meeting specification was limited to whether or not the Healy SVS met spe- cification when energization was occurring from the north (ie.,O Gold Hill towards Healy power plant).Finally,the motion requested that the harmonic testing being jointly conducted by the Alaska Power Authority and Golden ValleyElectricAssociationbeturnedovertotheAlaskaPowerAuthority "for,their een.4S me a,..eo a ee!-abalasy Liisi ana Lekate edsoi ie Se a sa OP February 14,1985 AFIOC Minutes Page 5 John Marshall then motioned for the Operating Committee to take aformalpositionstatingthattheOperatingCommitteedoesnotfeel or believe it is an acceptable practice to de-energize or remove aportionoftheRailbeltInterconnectedUtilitySystemgenerationasaconditionofenergizingtheSVSsystemattheHealygeneratingstation.Marvin Riddle seconded the motion;the motion was approved unanimously. Marvin Riddle then motioned for the Operating Committee to requestthattheAlaskaPowerAuthoritydirectGilbert-Commonwealth to update the December 31,1984 Anchorage/Fairbanks Data Link Requirements booklet to reflect the Municipal Light &Power/Golden. Valley Electric Association SCADA Vendors Functional SpecificationfortheAlaskaIntertiewhichwasissuedonJanuary22,1985.Mike Massin seconded the motion;the motion was approved unani- mously. Turning to subcommittee assignments,Acting Chairman Marshall then directed the DISPATCH/SCHEDULING AND RELIABILITY/CRITETIA SUBCOM- MITTEES TO JOINTLY MEET ON WEDNESDAY,MARCH 20,1985 AT 1:00 P.M.AT THE GOLDEN VALLEY ELECTRIC ASSOCIATION OPERATIONS BUILDING for the purpose of jointly reviewing the Gilbert-Commonwealth Operating Spinning Reserve Verification Study which will be made available to the subcommittees when they arrive at the Fairbanks meeting.Additionally,the Dispatch/Scheduling Subcommittee isdirectedtodevelopinterimintertie:.loss determinations.usingtheGilbert-Commonwealth Load Flow Intertie Feasibility studies which were conducted earlier. THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE AT 9:00 A.M.ON THURSDAY, MARCH 21,1985 IN THE ELECTRIC COMMISSION CONFERENCE.ROOM OF FAIRBANKS MUNICIPAL UTILITIES SYSTEM AT 645 FIFTH AVENUE, FAIRBANKS,ALASKA. Larry Colp then motioned for the meeting to adjourn.Marvin Riddle seconded the motion.The Operating Committee then unani- mously approved the motion to adjourn at 4:25 p.m. Rgspectt V7submitted,Miké Massin -WO fossrAnchorage/Fairbanks Operating Committee MEM/csn Attach.1.March meeting agenda 2.Minutes from the joint SCADA/Metering/Communications- Dispatch/Scheduling Subcommittee meeting held on 2/5/85 3.Functional Specification for the Alaskan Intertie Data . and Control Network Software 4.Hand out furnished by General Electric on SVS start-up 5.Copy of letter to Lisa Rudd,Commissioner of Administration 6.Letter from Alaska Power Authority regarding APA repre- sentatives for the Operating Subcommittees 7.Letter from Alaska Power Authority regarding GE presen-tation on Static Var systems a fo, Minutes furnished by Morrison-Knudsen Anchorage 7Fairbanks Intertie Uperating Committee -AGENDA- Thursday,March 21,1985 Begin at 9:00 A.M. I.Adoption of prior meeting minutes II. III. Vv. O vi. Approval/modification of agenda Committee correspondence and reports A.Reliability/Criteria Subcommittee B.Dispatch/Scheduling Subcommittee C.Intertie Status Update (A.P.A.) Visitor comments related to items on agenda Old business New business A.Recess and work session B.Dispatch/Scheduling C.Reliability/Criteria D.Election of Operating Committee Officers E."Other Formal Operating Committee actions/recommendations Subcommittee assignments Set agenda for next meeting Adjournment Adjourn by 3:30 P.M. Meeting location:Fairbanks Municipal Utilities System 645 -5th Avenue Fairbanks,Alaska (907)456-1000 -Frle.LAIKA "Corl afTokerve(isi)voi enero TO:Distribution DATE:January 22,1985 cc: FROM:W.Bounds Gs /biaree™Forye)vSUBJECT:Functional Specification for Intertie Ml pivlepst! Enclosed is a draft copy cf "Functional Specification for The Alaskan Intertie Data and Control Network Software". Par the agreement on January 8,1985,LGS is distributing the document for review and formalization.Our understanding is that the document will be formalized and then returned to SCI and LGS for acceptance. ftgm Enciosure Distribution: Robert Boardman,Systems Control,Inc. 1891 Page Mill Road Palo Alto,California 94303 Robert H.Cay,?.E.,Anchorage Municipal Light &Power1200EastIstAvenue'/ Ancnorage,Alaska 99501-1685 Barry 0.Lyons,Gilbert/CommonwealthSeattleOperationsCenter 14450 N.E.29th Place,Suite 217 Bellevue,Washington 98007 A tephen t..Muchlinski,Gilbert/Commonwealth Seattle Operations Center 14450 N.E.29tn Place,Suite 217 Bellevue,Washington 98007 Robert Orr,Golden Valley Electric Association Post Office Box 1249 Fairbanks,Alaska 99707 Le”fresaema anny NEOA ah ye .: 2 ::a a "ee ao eed g aap Me . .WS *.Se .Log,tory .:eo pe eGentibtsensZedeat:cleacs Leal be alas cs a Mie MMe kee eri ete ie a a Sh ea ah tea i i ab Aram eh aire ee Dr Loy Libba ewdintena dd FRFUREFFPF FFEFFREFFF FFRFEFFFFFF VUTUVTVATT TTA TT TTT T9944 1 9999910999999999099199919119119191119119111' TUTT99099704777977701977994 Digital Equipment Corporation -VAX/VMS 144999129919919919799999999979919119991991111911199911111111111111111' 00090909 00000099 DD 00 30 DD -DO 0D 00D BO OB)DD DO DO 129)DO 090 DD DO bo eB)oO 900090095 ovo000000 ppoo iL SSSS D OL S D DL 5 D DL SSS 9 DL S D DL 5 DDD LLLLL SSsSss AAARAL TUTITTTTIT AARAAR Lt AAAAAR TITTTTTTTT ARAAAA LL AA AR TT AR AA LL AA AA TT RA AA LL AR AR TT AR AA LL AR AR TT AA AR LL AA AA TT AA RA LL AA A TT AA AA LL ARRARAAABA TT ARAARARARA LL ARAAAAAAAR TT AARAAAAAAAA LL AA AA TT AA AA LL RA RA TT AR AA LL aA BRR T AR AA LLLLELLLLL aA AR TT AA AR LLLLLLLLLL SSSSSSSS.PPPPPPPP CCCCCCCC 333 SSSSSSSS PPPPPPPP ccccccce 333 SS PP PP CC ,333 SS PP PP CC 333 SS PP PP CC ss PP PP CC SSSSSS PPPPPPPP cc 333 SSSSSS PPPPPPPP CC 733 SS PP cc 233 SS PP cc 233 eeee SS PP cc ; wees SS PP cc 2 eee SSSSSSSS PP CCCCCCCC 33 aaee SSSSSSSS PP CCCCCCCC 77 File _ORSOsCGVEALDLS.DOCIDATALINK.SPC31&4.(4398-1770)4 last revised on 21 JAN-198 The records are variable length sith implied (CR)carriage contro Job DATALINK (€106)queued to SYSSPRINT on 22-JAN"1985 13:65 by user OLSs UIC CTG started on printer _LPAO: FFFFFFFFFF "FEFFRFFF *FRFFFFFF on 22°JAN 1935 13:09 from queue LPAG. PRRSPRRRRCRPSEEREREOSRRPROSERESEROSEROEERESREREESERREREOREREERE19941919999191191991177791111'Digital Equipment Corporation 7.VAX/VMS POS PPPERORORE EPEC ROCCOCS SO PERER EERE RREREE PEERS ERE EER ROSE RRO REE RER' Lys hidae toons ry SOE aeae ee wie ES aa ee ah a aRi ee Be ae lel a * 2 A inantoeSoints eR name Tia ta a I ae a FUNCTIONAL SPECIFICATION FOR THE ALASKAN INTERTIE OATA AND CONTROL NETWORK SOFTWARE 1.0 GENERAL he utilities involved in the control and use of the Alaskan Intertie eed to exchange data concerning conditions relative to the Intertie on a periodic and as-needed basis.This data is to be exchanged across a data link between cooperating SCADA/EMS systems at the various utilities.The following functional specification defines the miniznum interface requirements imposed on any utility joining the Alaskan Intertie Data and Control Network. Due to the differances betszeen each SCADA/JEMS vendor's data storage/ retrieval mechanismss the term "data base”in the following document should be interpreted to mean the general pool of inforsation available to the SCADA systen. i 2.9 DATA LINK NETWORK TOPOLOGY she Oata Link network consists of 2 or more cooperating SCADA/EMS facilities comaunicating over standard DECnet circuits.There must be at least two separate physical pathways between any two facilities in the network in order to provide redundancy.Optimally,the two different pathways should not have any intermediate nodes in common. Thiss however,may not be feasible in a large network or because of geographic reasons.AS each new SCADA/EMS systemis addad to the networks,the impact on the existing network configuration will have to be considered and a new topology implemented. Since many SCADA/EMS systeus consist of multiple CPUs,of shich more 'than one may be the "primary”Cisees:currently dominant SCADA CPU). the physical links between any two SCADA facilities may be switchable between more than one DECnet node at that facility.This must ba taken into consideration in setting up tha DECnet data base at each facility and also during data link software implementation. SO IEE aorta ee a Cita ned AEsrade+ated its Lae saa ae OE es ie a 3.0 DATA LINK FUNCTIONS t the highest levels the data Link software exchanges data packets across a DECnet link to another SCADA/EMS facility.These packets are rigidly formatted according to predefined data list descriptors. (The layout of a data packet is defined in section 5.0.Section 5.2.1 describes data list descriptors and their correlation with data packets.) The disposition of data received from a remote facility is up to the individual implementation of the data Link software at the receiving facility. Specific data link functions are as follows: -Establish DECnet connections for task-to-task communication with defined DéCnetvobjects executing at renote facilities Format a data packet using data from the SCADA/EMS environment -Transmita data packet to one or more facilities Receive a data packet from other facilities Unpack a received data packet -Respond to a request for data transmittal received from a remote facility -Echo diagnostic type buffers back to the originating facility a Sia hl aa os a aehandOL eei oll Saat taiNreed ie te ate Wee ea SR SO ee Aa eae a ded cL oa a ale ee "20 DATA LINK COMMUNICATION MOOEL the Data Link communication:model may be pictured as a layered structure in the following fornat: bd SCACA/EMS DATA 3ASE 2 VENDOR te------renee ea ae cena PROS a orb H----%RESPONSISILITY :LOCAL OATA LINK SOFTWARE $ Pw mw eww ewe we ewe ow wwe wees ©oe we ew oe eee we we we =o ww ww wee ww wee we ew ee ween :DECNET SOFTWARE 3 ta wenn nena ene n eben anne woot en ese e ament DEC RESPONSIBILITY -Pd ..DECNET PHYSICAL LINK :3 re a ne nn en oe en oe ne + 4.1 DECnet Physical Link j* Tha DECnet physical link between any two "neighbor”Cisees immediately Maaradjacentonthenetwork)facilities must be determined by those two ie pefacilities.The only restriction is that the physical Link must oP Wey peessupportalltherequirementsestablishedforthehigherlayersinthe3-model.In generals new candidates for network membership must use 3 :aphysicallinkcausingtheleastamountofimpactonexistingmembers.io Each node on-tha network must have at-least two physical data paths to:adjacent node€s)and must have the capability to performs natworkrouting.Lo «2 DECnet Software All nodas on the network must have DECnet Phase IV with routing Capabilities.D&Cnet Phase YII nodes may be considered if all functionality raquired by the rest of the model is provided.DECnet flow control must be implemented at each facility. 4.3 Local Data Link Software Specific methods of implementation for the facility-resident Data Link interface software is left to the individual vandor/utility.ALI implementations wills however,conform to the following.specifications: a)All data link communications take place using the DECnet task-to-task cousunication capabilities. b)Tha software which receives:data across the data link from a remote node will be installed as a D=Cnet: object. we BR be Aaa ie ead nae a ate eal Sh at i abs Wak FR eevee at ea Fe :.on Sb oe aati be ae eae De rateeelia Me aed oe c)The installed DECnet object will have the number 128. d)The software on each node must be able to support theconceptofmultipleODETnetnodesateachremote facility. e)The software on each node must be able to support a minimua of 2 DECnet logical connections to each renotea facilitys one for sanding and one for receiving f>The software which sends data across the data link to a remote node will be responsible for initiating the DECnet connection to tha remote receive software C=object number 128 defined above) 9)The responsibility for eastadlishing logical connections to remote DECnat software is defined as follows: 1)On systam initialization: The sending software on the system joining the network initiates the connectionto each renote node.If a rejection from a remote node is received or the remote node is unavailablesthen tha sender inspects its own tables to see if an alternate node name has been provideds and if sos the connection is retried to the alternate. The renote receive software will verify that it is running on the currently "primary™CPU. If it is nots it will reject the connection. Otherwises it will accept the connection request. Once the remota receive software has accepted a connection requests it notifies its send software of the established connection.Its send software then initiates a connection sith the receive software on the initiating node. Data packet axchange does not begin until both connections have completed successfully. Ms Oe ire eis Ct OE Oe une teld om ORE Naa il call Sa RE ies eee a el ducted ee tet ea ee ab rt teat es eae EE Ue a A ea eb OS a eBaetrai h) i) k) 1) 2)When a Node Secomes Accessible When a network node which was previously non-accessible becoues accessibles each facility detecting this change is responsible for attemoting to establish a connection with that node. When a new connection is established,it is the responsibility of each facility to send the latest copy of all periodic lists destined for-the other end of that connection across the data links regardless ofthedefinedperiodicityofthelist.; Fach facility must be able to process all the data packet types defined in section 5.0,below. Each facility is responsible for sending data packets to remote facilities under the following circumstances: -on a periodic basis -in response to a dispatcher's demand -_in response to a remote request for data -in responseto a.triggeringaventon the system A facility which is disconnecting from the network Cfor failover or other reasons)should atteapt to disconnect fron other facilities on the network gracefully.All data link software must "be sufficiently flexible such that adding a new facility:to.the network has aminimalimpact.::, 4.4 SCADA/EMS Data Sase The data base configurationand interface software is normally unique to each of the cooperating facilities.The only:data link requirement is that the data link software be able to retrieve the current values for defined data points and transmit them in a formatted packet to the cooperating remote facilities. SW Nan ek ee aT Tents ta nan BE ts eat tate tae .:we ee See ene aa ee Ye ee s.0 DATA PACKETS oecause of the need to support a wide range of different data base interfaces,all data transfarrad across the data link will be loaded into fixed-format data packxetss conforning to a data represantation- convention specified for each possible data type.Each individual facility is responsible for formatting the data packets which it sends to other facilitiess and for unpacking data packets received from other facilities.No data may be sent or received which does not reside in a pre-defined data packet. Data packets may not exceed 8093 bytes.It is recommended that all data packets be kept at or belos a maxinum of 576 bytes. The data packets exchanged across the data link consist of tuo distinct segments:fs 1 -the packet header 2 -the packet dats 5.1 Data Packet Header The data packet header has a defined format which nust be followed by all facilities when preparing a packet for transmission.The header is laid out as follows: 1 [Ts 5 C $wwewnwe ew ewww ae cee Oe me oe awe eee eo ewe ee ww on} :SOURCE FACILITY : Fw eee ewer ooeere OT =-4}<4 :DATA LIST TYPE :: teoccer-we wernmnence en wer rar ewe ee een emt 6¢-List Identifier :DATA LIST NUMBER :: $eneet a a we re we ew ee eee ¢<-+ 3 DATA BYTE.COUNT : $wwe re ww ww wwe we we we en en ew ee weeoeFe =F :MONTH :: :DAY :#-Date Stamp to-----Serer ee 2-2 ----+-----eeeetoe-=t 3 YEAR :: foe eeonee ew ee ee ea enn ee ee ee mma ae ws :HOUR ;:: $a weroeewwe woe eee =wee ee ee wee wwe wee =-orokoy 2 : 3 MINUTE :+="Time Stamp Ge eeee eo eee wewe wees =teneeee ee ee ee es a ae oe cee =oe >: :SECOND > $a ewww ew ee ee meee ween bee wee ee oe ee ee ee ee + + :RESERVED s NOTIFICATION FYEL): eee we wee a oe wwe ewe om mee wee wows ewww enw oe + :TARGET FACILITY : $ow ee ee een enn ee ne eae wee meen ot :RESERVED : §.0 FACILITY SPECIFIC FUNCTIONS A number of functions and capabilities are facility-spacific in definition and implementation.These include: -Event triggered List transmission Triggering of SCASA/EMS software by List receipt Historical retention of scratchpad or other data packets -Error handling 6.1 EVENT.TRIS ERED LIST TRANSMISSION There is'no''network:definition af an "event™or the mannerinwhichit is-detected.It is therefore left to the individual utility to identify and implemant those SCADA/EMS conditions which should Feasonablyrequiranotification of one'or more remote nodes of some Significant change.Alarmss changes in equipment status or changes inproductioncapacityordemandarelikelycandidatesfortriggeringevents. The basic steps in handling event triggered transmission are thease: 1)Recognize the occurence of the event 2)Associate tha event with a list or set of lists Sasa.123)Eormatcthesdata packat(s):for the 'associated list(s)= 4)Transmit the data packet(s)to the designated targetfacilities- . [Yne implementation of this functionality is not necessary for Particination in the networks.axcept-to conform to the Alaskan Intartie Bata and Control Requirements CAIOCR)as defined on-Oecember 31-1984.,:., b.2 sO TREGGERING SCADASEMS SOFTWARE The ability to trigger the running of application programs based on the receipt of a given list may or may not be required at eachfacility.It is a function specified in tha AIDCR documents but there is no defined interface with remote facilities so that they could intelligently trigger execution.The complexity of providing general case support on a multi-facility network would be enormously complicated.It is assumeds therefore,that each facility will define and implement an interface which would require thats upon receipt of list X-»program Y will be activated by the data link receiving software at that facility. Failure to implemant this functionality should not limit the Capability of any facility to participate in the network. ce a ee wD ante ae pad able etre A a at 6.3 HISTORICAL RETENTION OF SCRATCHPAD SR OTHER RECEIVED OATAO..will be a facility based decision hos to handle scratchpad informations and how much of it is to be retained.For those facilities which display the scratchpad data at a dispatcher's consoles it is probably desirable that they be capable of displaying the last N scratchpad buffers in an orderly fashion Cperhaps aven the last N received from any jiven renote facility).The fact that a dispatcher may find it necessary to continue a communication across more than one scratchpad transmission points up the naeds.Another consideratian would be that scratchpad buffers arriving in close order might tend to overwrite each othar if they are not buffered and retained to some extent. 8.4 ERROR HANOLING re The method of handling errors encountered during link transmissions is left up to the individual facility.DECnet will take care of a lot of the error handling.Where sone comaunication is still taking place, but the error rate is unacceptables it is the decision of each facility how to respond.The only requirement would be thats if afacilitydeterminesthatitwantstoseveraconnectionsthenit should attempt to disconnect gracefully Cand thereby notify the remote facility). 6.5 PACKET LATE OETECTION we i ability to detect an unaccaptable delay in the arrival of ascheduledpacketfromarenotefacilityisanoptionalresponsibility for each facility.Howaver,it is racomnended that each facility waincorporateWWV3timesynchronizationinitsSCADA/SEMS implementation a to provide for network time synchronization.(There is no other provision for time synchronization defined.)This will aid in determining whether or not a renote facility has failed to send a data packet on schedule. 0 re no oo,yd a ot . -reed :aad.set .;Cop Ante Saltsdi id a ad deo wot.ee EreTy ene OER SE wet ie!.aneneeeta incantationAene il a ta a tm a eo ©5.1.1 Source Facility The Source Facility field consists of a 16-bit integer value associated with the facility which senerated and transmitted the data packet.The facility identifiers are arbitrary,but must be unique within the data link network,Facility identifiers are assigned by convention.Multiple CPUs at the same facility share tha same facility nunber. Se1.2 List Idantifier A List Identifier consists of two subfields:the Data List Type field and the Data List Number field..7 "The Data List Type field consistsof a-T6-bit integer value which identifies the basic type of data occurring in the data portion of the packet.List type values are defined in an arbitrary fashions but aust conform across the entire network.The currently defined values ares: LIST TYPE VALUE DATA REQUEST ."-30 Lad se.SCRATCH PAD.wee.T3D -3 Loa ote a lee Bee _- ,OIAGNOSTIC TaD TED ao Data List Number identifies a list within a type.A list type/listnumberpair(Ca list identifier)together with the source facility identifiers is used to selact the appropriate unpack list descriptor. The list identifier alona defines the appropriate data packing descriptor on the source node. 5.1.3 Data Byte Count This is a 14-bit field containing the count of the bytes in the data segment of the data packet.It is treatedasasigned integer. 52124 Date Stamp The Date Stamp consists of 3 subfieldss each consisting of a signed 16-bit integer.Tha fields conform to the standard Date transmission format documented below (section 5.22264)-The Date Stamp identifias the date that the data was extracted from the data base. $.1.5 Time Stamp The Tima Stamp consists of 3 individual fieldss-each consisting of a signed 16-bit integer.The fields conform to the standard Time transmission format documented below. The time stamps in conjunction sith tha date stamps indicates whan the fata was extracted from the data bases not necessarily shen the data was actually transnitted. wR sett a ae Se ee Mat cele Ta Leet eI we ee a a a a Le ered we a ee tee te ber eae eitdi 2 ae 521.6 NOTIFICATION FIELO An 8 bit integer flag field is resarved to indicate that the dispatcher may need to be notified of the arrival of this list. Any further special handling of this field is facility dependant. The possible values for the notification field are: VALUE MEANING -1 This is a "scratchpad”list and the Operator should be notified of its arrival 0 No special handling of this list 1 This list transnission was triggered by an alarm occurring 5.2 Data Segment The data segment of a data packet consists of a number of data fields, each starting on a byta (8-bit)boundarys occuring in a fixed order defined by a data list descriptor. Solel Data List Descriptors Data list descriptors define tha orders type and field size for each data elemant in a dats packet.These descriptors are written in a descriptives high-level manner and transmitted between facilities independent of the data link Ci.eers:via mails telecopiers or sone other medium). It is the responsibility of each facility:to translate the data list descriptors received from other facilities into software/data base directives which provide for: 1)The extraction of the individual data fields from tha data packet 2)The conversion of the data from transmission.fornat into data base storage format 3)The storage of the received data in the appropriate location for any further handling eet cc,cn ei -es ca ok ceo ei ae eal vary 2a as a eae Sane arsele a cle ak Pe ae Tak esSe i,aS an Callie da ee RL aaa a abe ed Oe,Caen Bl va Oo typical data list descriptor might be as follows:Title:Interchange Schedule GVEA TO AMLP List Types:3 Schedule:Hourly 5 List Now:-5 minutes after the hour Sources GVEA Destinations:AMLP Field Description Data Type Field Length 1.Start Date DATE &bytes 26 Start Time "TIME 6 bytes 3.Stop Date :DATE -6 bytes 4.Stop Time TIME &bytes 5.Rate CMW/§)INTEGER 1 byte 6.Transaction (MW)/*INTEGER 1 byte 7.Local Price ($)\FLOATING POINT 4 bytes 8.Foreign Price (3) -FLOATING POINT 4&4 bytes 9.Transaction Type ASCII 2 bytes Note that the list is for a spesific interchange schedule.This allows interchange schadule lists to be received from various remote facilities and processed concurrently.Any given list defines only one set:of-data base storage locations.>.No special list handling may ever be assumed to be keyed off of the contents of individual fields within a defined data list. FO .2.2 Data Fields -Each data field must-be one of the valid data types defined below for data packetss and nust represent the value according to the conventions defined in the following paragraphs.The transaission format and the data base data format may differ for any given facility.It is the sole responsibility of the sending facility to convart any data fields into the transmission format before transmitting the data packet. The following data types are defined as being valid for data packet transmission: -Integer -Floating Point -ASCII -Date -Time -Status Indicator -Quality Indicator -Alarm Indicator -List Identifier Se el cs is aia Rl a MS Pa OT abs ho laa at ae med Ve el we oe cel at eal a ae Ba at.etnaa tet OT a Ba eb are ae So ,Sel2e2el Integer Data Integer data is transmitted in 1+2 or 4 bytes.Yt is normally treated as a signed integer value represented in 2°s complement form (DEC standard),with the high-order bit functioning as the sign bit. Selecee Floating Point Data Only 4 byte floating point (single precision)data transmission is supported across the Link.The representation format conforms to that of the Digital Equisment Corporation VAX and POP-11 floating point storage:oe"oeowo<wuo=am=eena>%"4)o=zosoennyPpoO 4-oO=eeAs described in tha VAX ARCHITECTURE HANDSOOK: "The form of an F_floating datun is sign magnitude with bit 15 the sign bits bits 14:7 an excess 128 binary exponents and bits 6:0 and 31:16 a normalized 24-bit fraction.with the redundant most sssignificant fraction bit not represented.=]Within the fractions bits increase in significance fron 16 to 31 and O through §.The & bit axponent field encodes the values G through 255.An exnonent valua of 0 together with a sign bit of 0,indicates that the F_floating datuns has a value of 0.Exponent valuesof 7 through 255 indicate true binary exponents of -127 through +127.Ceee-)The magnitude of an F_floating datua is in the approximate range «29810 **-33 through 1.7*10*«*38.Tha precision of an F_floating datun is approxinately one aart in 2**23 Capproximately 7 decimal digits.)” Se2eled ASCII Data ASCII string fields of 1 to 127 characters may occur in.a data packet. The length of any individual field is fixeds however.Only printable ASCII text may occur in the string.It is the responsibility of the software formatting a data packet for transmission to blank-fill any ASCII fields into which data shorter than the field length is being loaded.Only the ASCII characters themselves are transmitted in the lists no "string descriptor™or character count is included.NeB38er all alphabetic characters transmitted may undergo case conversion at the receiving facilitys so casa may not be significant. Oo a eS eT REC OCR PE TOREROTCoeTO ONES OSE Tn CS SD ee Cie .vb con wna a a ada Babine eee a AE OO un sats wed cade le aaa 5422244 Date Data ©.,conventions all dates transmitted in a data packet consist of three 16-bit intecer subfields containing the binary representation for the months day and year. The fields occur in the following order: FIELO VALIO VALUE RANGE MONTH 1 -12 DAY 1 -31 YEAR 00 -99 Tt should be noted that the standard FORTRAN intrinsic function IDATEreturnsthesevalues. Sete led Time Data Similar to the Date fiald conventions the Time field consists of three 16-bit integer subfields containing the binary representation for the hours minute and second of the designated time.The fields oeceur in "the following order: mp |FIELD VALIO VALUE RANGE HOUR 9 -23 MINUTE 0 =59 SECOND 0-59 Qmhours O-minutesr O-second €02:03200)is considered the first valid time on a given day.253259259 is considered the last valid time on a given day. St eam ae OA a alla enact BLES Laan eS oy de a Fie et bee a LAMM ee es i Ae RD ee a ee EE ee 204 §.2.226 Status Indication Jata©,status indication fiald consisting of one byte may be included in data packets.Since different SCADA/EMS systems nay have differant interpretations of status valuess by conventions status will be transmitted in thea following manner: fe Sending and receiving software at each facility will be responsible for translating back and forth between their own internal status representation and the data packet status representation. Se2e2e?Quality Indication Data It may be desirable to associate a data quality code along with a data field baing transmitted in a data packet.For this purposes a Quality Indication field consisting of ane byt?has bean defined by convention 1°have the following implementationsVALUSMEANING Sending and receiving software at each facility will be responsible for translating back and forth between their oven internal quality indication representation and the data packet representation. oO .:."a idatsiRintaameltcaainechalbaateaADeionteeeRoneenvocodesiathPannenastonsataaisbiteLiveBaeredeslleteenaradnteesmerkenedsaci Q°°°Alarm Indication OataAnAlarmIndicationfieldone byte long may be included in a data nacket list to indicate the current alarm stata of a psint shose value is being transmitted in that list.This will be useful for lists whose transmission was triggered by an alarm condition (Cassuming that the triggering point is included in tha list),since the receiving facility will have some indication of precisely which point(s)on the list triggered the transmission.The alarm field has the following values: VALUE MEANING 0 Point is in a normal state 1 Point is in an alarm state Sete 2eF List Identifier Data List identifiers may only occur in list request packets.All list idendifiars have the same format (two 16-bit fields)described insectionS.1.2 above. need a €Poe Tot :cee a523'SPz CIAL PACKETS ID°"packets require special handling.These include:-Scratchpad Packets.. -Data Kequest Packets "--737> Diagnostic Packets 5.3.1 Scratchpad Packets A Scratchpad packet consists of a packet header and a 2S6- byte data segment.The data segment iss by.conventions.considered to consist of. four 64-byte lines of character data.Only printable ASCII character data may occur in the data segnent.Each facility in the network must provide the capability to: -accept scratchpad input from a dispatcher -send 3a scratchpad packet to any other facility in the netpork -receive scratchpad packets from any other facility -present the received scratchpad information to the dispatcher The purpose of these functions is to provide a communication path between the operators at any two facilities.The implementation of this functionality at a given facility is required,but may be performed in any manner which supports the exchange of unformatted ASCII dats. Scratchpad packets have a special code in the notification field of the packet header to support the capability to notify tha dispatcher that a scratchpad message has arrived. yo Data Request PacketsDatarequestpacketsallowa ranote facility to request thea transmission of a specific list or group of lists from any given facility on the network.A data request packet consists of a packet header and a data segment containing thea list identifier(s)for the lists which the requesting facility wishes to receive.The data segment may be variable length or fixed lengths depending on the requesting facility.Any invalid or unrecognized list identifiers a3re simply ignored by the facility receiving the request.The raceipt of a data request should not have any inpact on the scheduling of periodic lists.The list identifier(s)are in the format described in seztion 5Sele2s above. Each facility has the option of "protecting”its lists from being requested by a remote facility;to shich it does not wish to send thedataeInsuchacircumstanceritshouldtreatthelistidentifieras invalid and simply ignore it.Howavers no list whith would otherwise be sent to a given remote can be protected fron data request transmission. 523-5 Diagnostic Packets Diagnostic packets are another packet type which does not have an associated data list descriptor.They consist of a diagnostic header and whatever data the requesting facility wishes to send across the Link to a remote facility.Every facility in the network must provide the capability to receive a diagnostic request packet and simply echo back the data segmant to the originating facility in a diagnostic reply packet.This provides an elementary first level diagnostic Capability which can be run between active SCAIA/ZEMS systens when conmunication problems are suspected. Joanennhaden a nacht See a sel Koi Rca he Mel lara!8 et a ae tlae tna Sali,Boedew" CONTRACTORS ENGINEERS wins,DEVELOPERS ae =”MORRISON-KNUDSEN COMPANY,INC. ANCHORAGE-FAIRBANKS INTERTIE 813 D STREET ANCHORAGE,ALASKA 99501 PHONE:(907)274-9566 February 21,1985 S/N-M-K-0873 Anchorage Municipal Light &Power 1200 East 1st Avenue Anchorage,AK 99501 Attention:Mr.Mike Massin Subject:G.E.PRESENTATION AT THE OPERATING COMMITTEE MEETING Reference:Anchorage-Fairbanks Intertie Project Gentlemen: Enclosed please find our notes from G.E.'s presentation at the Operating Committee Meeting on February 14,1985 regarding the SVS System. Very truly yours, MORRISON-KNUDSEN LLL C.R.Parrish Construction Manager RK/gki Attachment 1 -(8 pages)Attachment 2 -(3 pages)Attachment 3 -GEK-75511B (5 pages) cc:D.Eberle -Alaska Power Authority Commonwealth Associates,Inc.-Anchorage,AK Commonwealth Associates,Inc.-Jackson,MI tas aaa VE aes p ju.i.pe ike i eek ee nad vie Dah raeEe at ed caeiaS ae Bosaber ATTACHMENT 1 G.E.PRESENTATION AT THE OPERATING COMMITTEE MEETING,ML&P Mr.Fink presented an experience list of G.E.Static Var Control installations. Mr.Miske handed out a sheet,showing the time phased variation for TCR, Capacitor,Control,and System Voltage during the planned SVS start-up and explained and described the sequence of events that goes into starting the SVS System. -HV Transformer is energized which provides control power to the SVS System. -SVS Breaker operates and picks up TCR -Very low level of conduction initially. -When the control is satisfied that everything is OK;it will proceed to ramp up to a higher level of conduction.This occurs over a period of approximately1 second.The system voltage will drop as the TCR is ramped up. TCR at GH &Teeland will ramp up to 10 MVAR inductance.At Healy to 22 MVAR. -Control directs the closing of capacitor switch. -Total time of above operation is approximately 5 seconds.There will be a few cycles pre-strike.The system voltage will rise. -The auxiliary switch on the capacitor switch closes and initiates the automatic voltage control mode bringing the system voltage back to the pre-start level.ene -Higher voltage period is approximately 8 cycles. , . Ce ee,;i-.Under-voltage periodis approximately 5 seconds.:Se a ee beea Pte 4waPAGEDaeweedEeESSeeSeeeeuinaeah2A 3) -At the start of the process the SVS remembers the system voltage and at the end of approximately 6 seconds it brings it back to the original level. -The system voltage can then be regulated using the thumb control. Mr.Miske then addressed the question of magnitude of the voltage fluctuations. Goldhill -When the TCR is ramped to 10 MVAR inductive the system voltage at Goldhill will be pulled down approximately 3%.This assumes a minimum generation condition.The voltage drop will be approximately 4 that amount at full generation.When the 33 MVAR of capacitance is switched on,the voltage will go above normal by approximately 6%.That will be the voltage at the Goldhill bus,it will be better at the load end. Marvin Riddle commented that at min.generation the GVEA System may not be able to stand -10 MVAR.If the Healy machine is the only one in service, there is not 10 MVAR capability. Discussion ensued with regard to the assumptions made for the min.generation condition.It was concluded that the GE studies did not accurately reflect the GVEA preferred operating mode in that the Healy generator was assumed to be not running when in fact the Healy machine is the base load machine and will normally always be running. Teeland -When the TCR is ramped to 10 MVAR inductive the voltage at Douglas will drop by approximately 3%.When the capacitors are switched in,the voltage will go up by 6%,or 3%above the initial system voltage. '>Page 2errsva»_ete pa mt Para ae Sila wa nd EE Payeeen eae?Eeeee eeaT 7 The GE studies assumed that 5 Beluga machines were on and the Intertie was off.Mr.Marshall commented that was not a min.generation case.Dr. Prabhakara was asked what assumptions were made in the G/C studies.Those assumptions were concluded to be more realistic as a min.generation case. Mr.Marshall commented that he did not have any problem with the anticipated voltage levels. Mr.Hall commented that he did not have any problem with .90 p.u.at Douglas. Healy -The assumptions are that the Intertie will be energized from the South,the Intertie line is in service from Douglas to Healy,the Healy SVS will be energized from the line.The voltage will be 112%at the end of the open line.When the TCR is ramped up to L =C of 22 MVAR,the voltage will be pulled down to 90%.When the capacitors are switched on the voltage will go back 112%,on the open line.At this point,the SVS is not connected to the distribution bus.The system voltage can then be adjusted using the thumb wheel before closing the line breaker. The voltage fluctuation will be somewhat less at Cantwell.The 40 miles of transmission line is equivalent to 6-7 MVAR so the effect will be about 2/3 what it is at Healy.The equipment is rated for over-voltage with this in mind.The transformer also has a load tap changer.Initial steady state voltage can also be adjusted using the thumb wheel and execute button when energizing the Healy SVS. Mr.Riddle raised the question of what happens to the voltage if the Intertie 7 has to be picked up from the North. -Page3 : ck Nic cepitind:chk calle ip aba etnies Mert cant ic a fa Pe A al a i lMai Te GE IO A ct A tc Se lan ale dat ei eae Feat dec Mr.Miske responded that the situation is not very much different.The voltage will drop 20%.If that is a concern then GVEA may want to bring the voltage up before starting,say to 105%,then voltage dip will only be to 85%.But really,80%for 5 seconds is not too bad. Mr.Riddle commented that his concern was not so much the voltage as the capability of the Healy machine to absorb the 22 MVAR.The unit is rated at 10 MVAR and we will be switching 22 MVAR.How will that affect the voltage regulator. Mr.Miske and Dr.Prabhakara concurred that the Healy machine should be able to handle it.The steady state capability is 17 MVAR lagging.It would be expected that about 15 MVAR would be picked up by the machine and the rest from the line. Mr.Riddle commented that 20%switching surge is pretty serious for the GVEA system. Mr.Miske again remarked that 20%switching surge need not necessarily be the case in all starting conditions.GVEA may want to bring the voltage up, depending on the system conditions,before starting the SVS,thus reducing the voltage dip. Mr.Riddle asked about the effect on the Healy machine of starting the Healy SVS from Healy. Mr.Miske stated that it was because of that concern that GE had recommended _that the Healy SVS not be started with the Healy generator.They had been "nes fo:2 Le -.. ..Tee .ate oe >:ng Soca sittinace oS ee ea ee eer 4 "_:Page isc etc pak a ok ae a it ee saab Sh ca talking internally with their generator people and had brought with them a brochure on Generator Operation (Copies of Generator Instructions GEK-75511B were passed out to all attendees).Mr.Miske advised that the section on torsional vibration on Page 8 described the problem.Time was taken to read that section. Mr.Miske explained that for there to be a problem two things have to happen. First,there has to be harmonics coming in and secondly the mechanical frequency of the buckets has to be the same value as the incoming harmonics. With the present state of the art,this cannot be calculated with enough accuracy to make a prediction.The possibility of damage occurring is extremely remote but the possibility is there.For that reason,GE's recommendation had to be to not start the Healy SVS in synchronism with the Healy machine. Mr.Riddle commented that he suspected that under the circumstances that would make it expedient to start the Intertie from Healy that the Healy generator may be off anyway. Discussion ensued concerning the conditions that might dictate start-up from Healy,such as a fault near Pt.Mackenzie causing the Intertie to open at Healy from an out-of-step condition.It was concluded that it would only be necessary under highly abnormal conditions. Mr.Riddle explained the problems and sequences required to bring the Healy machine,which is a steam unit,down to take it off line.The conclusion was that by the time everything got organized it would probably take an hour. Dr.Prabhakara stated that what GE 'seemed to be implying is that it is not .7 recommended to start the Intertie from the North. sabeine the i Sttsa:Bi a saémaiais oc tb aaa ibaE Pere aS Ex ate re a a i eer ea inha atk Mr.Miske said that is not necessarily true.There are some people in the generator department who just don't see how it could possibly be a problem considering the age of the machine and the fact that it has almost certainly experienced some considerable level of harmonics during its life time without any problem.Also,the fact that the Healy unit is a relatively small machine with a very short shaft length greatly reduces the probability of there being any damage.However,considering the implications of liability to GE,they cannot recommend that the SVS be started with the Healy machine on line. Mr.Miske suggested that it could be educational to measure the level of harmonics currently going into the Healy machine.This could be done in one or two days time with the use of a spectrum analyzer. Ensuing discussion brought out that Usibelli has a SCR Converter connected relatively close to the Healy machine which is almost certain to be putting out some harmonics.The question was raised as to the possible affect of harmonics on the Usibelli inertia wheel-load stabilizer.Mr.Miske commented that it had no buckets and would not be affected. The question was raised as to what measuring the harmonics would prove. Mr.Miske summarized by saying that the harmonic measurements would not make GE change their recommendation.However,it would give GVEA some perspective from which to assess whether the additional harmonics contributed by the SVS during start-up will really be significant. Page 6 * wk og vedanta ne ciA a Ste 2 acta ea ce ee ene a nee aa Mr.Marshall commented that what all this leads to is that we are getting back to what we decided a year ago in Schenectady,the recommendation is that we don't energize the Intertie from the North. Mr.Riddle commented that the only concern is that one dark night we may need to.99%of the time the Intertie would be energized from the South.Maybe that will be OK. Mr.Hall noted that it would normally be only the Douglas load that would be . affected. A question was raised as to the number of increments of voltage adjustment available with the thumb wheel switch control on the SVS.Mr.Fink commented that he didn't know off hand but GE would be conducting an operating/mainte- nance training school at each site which would familiarize operating personnel with all pertinent operating characteristics of the SVS. Ensuing discussion concluded that the thumb wheel switch operates in 1KV increments through seven steps and that it can be adjusted locally or remote by use of the SCADA system. Mr.Marshall asked how much voltage support could be supplied to the Teeland bus.The response was 6 to 7%. Mr.Marshall commented that the new 250 MVA transformer being procured for Teeland has an on-load tap changer on the 115 KV side. Arum Datadaiite Silt 2dr AS TN SO DOT ET Wor 2 Se NS SRS TR ene SRE POT CB Aa elt DN ea eS a del rs cna aE a ae Mee ie a te lian Oda eal 'BoefeaovisMaterTDon, GVEA raised the question of whether voltage control can be maintained on the Goldhill bus without access to the SVS. Dr.Prabhakara advised that the studies showed that the Intertie voltage can be maintained with either the Teeland or the Goldhill]bus out of service. There could potentially be a problem at very light load,but that problem would be in the Southern system,not the North. The question of starting up the Goldhill SVS during min.load conditions was discussed further.G/C agreed to run a load flow to determine if there might be a problem.The parameters were established as having the Healy machine on along with one 20 MW steam unit in the Fairbanks area.It was agreed that this is a separate item which might identify a potential "operate with caution"situation. The Chairman asked if there were anymore questions for GE.There were none and the meeting adjourned for lunch. DEC/RK/gki Loe:wee 4 ot rd ne ::eet og woe ne ears a 2p,4iad¥fein watemaLX suntan ttt rai are oS FS,ia Sh tan tecaes "mails id.de ae ita a Re RRS OR PIRC TS TS OPER CON Fane ae PE OO OUEST SE ATT | C ATTACHMENT 2 PLANNEQ VS STARTUP C 6 'Sec Ca pacctor E nec zed Condcol Ne teae To S ystenloagg -Page Lof 3 - _a is puce-wnctuan Se Abani _ce,cccigel ieee voip Lis ents inten ELECTRIC UTILITY VOLTAGE AND STABILITY APPLICATIONS: GENERAL ELECTRIC COMPANY.STATIC VAR CONTROL EXPERIENCE LIST Customer Basin Electric Hydro Quebec (Canadian Hydro Quebec (Canadian Hydro Quebec (Canadian TVA (4 Systems) Utah P&L El Paso Electric Texas Electric Service Alaska Power Authority Alaska Power Authority Alaska Power Authority *Scheduled Dates KV 13.8/115 GE)24/230 GE)22/765 GE)22/765 6.9 13.8/138 13.0/345 13.8/138 Teeland 13.8/138 Healy 12.0/138 Gold Hill 13.8/69 SVC MVAR 10/30 84 315/330 (2 units) 115/330 (2 units) 5/10 300 150/25 150 22/22 33/22 5/33 In Service Date 1977 1978 1980 1982 1982** 1984 1984 1984 1985* 1985* 1985* **Shipment date -Start.up not scheduled due to nuclear plant delay. DOC 1598A Page 2 of 3 PemaaraeeeeaePoreSVC In Service Customer KV MVAR Date Nebraska Public Power I 13.8 25 1973 CF&I Steel Corporation 34.5 50 1973 CF&I Steel Corporation (Uprate);100 1976 Saskatchewan (Canadian GE)13.8 25 1973 AFL Falck I (Italy) ) 14.0 50 1976 Nucor Steel I 12.5 25 1977 Nucor Steel II 13.8 40 1979 Acindar (Argentina)33.0 120 1979 Nebraska Public Power II ) 13.8 65 1979 Nucor Steel III 34.5 30/70 198] Florida Steel "33.0 80 1981 Georgetown Steel 14.4 60 /1981 Knoxville Iron 13.8 30 1982 BKN (Yugoslavia)35.0 60 1982 Italimpianti 33.0 200 1985* ROLLING MILL APPLICATIONS: ; °SVC In Service Customer KV MVAR Date AFL Falck II (Italy)14.0 30 1979 _Sidor I (Venezuela)13.8 25 1985* 'Sidor II (Venezuela)13.8 45 1985* *Scheduled Dates DOC 1598A :Page 3 of 3 era sie ela hai the ek da Sa a laa GENERAL ELECTRIC COMPANY|STATIC VAR CONTROL EXPERTENCE LIST ARC FURNACE APPLICATIONS GENERATOR INSTRUCTIONS GEK-75511B GENERATOR OPERATION LIQUID COOLED etonersOPERATING CONDITIONS NORMAL Prior to Startup Startup Shutdown *Power Factor Adjustment Effects of Leading and Lagging Power Factor Operation of Gas Coolers Operation with Unbalanced Armature Current (continuous and transient capability) *Harmonics Inspection Following a Tripout ABNORMAL Operation with Overload Loss of Excitation Abnormal Voltage Operation Synchronizing Qut of Phase Short Circuits Line Reclosing Switching Transients Off Frequency Operation Operation Without Stator Winding Liquid Cooling Operation on Loss of Stator Cooling Water Flow PRIOR TO STARTUP If the average internal temperature of the generator or exciter is below 20 C,the generator or exciter should be prewarmed to this temperature at a rate not exceeding 10 C per hour before ex- ceeding 83.3 percent of rated speed. If the generator or exciter has been shut down one hour or longer,the inter- nal temperature will be approximately equal to the temperature of the gas Copyright 1983,General Electric Company returning to the hydrogen or air cool- ers.Startups subsequent to shorter off-line periods should not result in low average internal temperatures. All protective devices and measure- ment instrumentation are to be confirmed as being in service,calibrated,and functioning properly prior to startup. All generator auxiliary systems should be checked out at this time to ascertain their operability and they should be put in service. These instructions do not purport fo cover all detuils or var in ipment nor to provide for every possible contingency to be met in ction with instollati »Operation or maintenance.Should further information be desired or should particular problems arisewhicherenotcoveredsufficientlyforthepurchaser's purposes,the matter should be referred to the General Electric Company. GENERAL@@ELECTRIC & 9b ip pShecea rStham ae at BhSEDI aeshsd «+ can hk GEK-75511B A conservative basis for estimating zero phase sequence loading,or combined negative phase sequence and zero phase sequence loading,is the following: Combine the per unit zero phase sequence current,Ip,and negative phase sequence current,I5,components according to equation (1),and observe the same limi- tations for the resulting equivalent current,I',as shown for Ij.This rule is conservative,but generally should be adequate for the rather rare situations where it is necessary to impose zero phase sequence loads on turbine-genera- tors. I'=Vu)”+(1,)°(1) Transient Operation with Unbalanced Armature Currents The capability of the generator to operate with unbalanced currents in ex- cess of the continuous values defined in the preceding sections is limited by the thermal capability of the generator ro- tor.The generator rotor will with- stand,without injury,unbalanced short circuits or other unbalanced conditions on the system or at the stator terminals resulting in values of Ip%t up to the values listed in Fig.2.This capa- bility is defined in terms of the inte- grated product of the square of the generator negative phase sequence cur- rent (I9),expressed in terms of per unit stator current at rated KVA,and the duration of the fault in seconds (t).This value is Ip*t. Directly Cooled Permissible Generators 137t up to 800 MVA 10 800 MVA to 10-(0.00625)(MVA 800) 1600 MVA >;no tae oles cee ,oe -.us .canoe ea oot =2 ee ee a na ACO a AR SR lt aac a ia Rt le 0 sare ace lh int ral a ee inwisHast Saeed ote he aN Pg"a DIRECTLY COOLED=to ;-_ 1 s+-----------4----------> '' !i 600 1600 GENERATOR RATING (MVA) Fig.2. HARMONICS Harmonics contained in the voltage and current at the terminals of the generator have two effects of interest. The harmonics produce additional losses within the generator,resulting in added heating.In addition,the interaction of the flux fields for the harmonic and fundamental frequencies produces torques on the rotor.The resulting torsional oscillations can in worst cases cause damage to turbine-generator parts. Sources of supersynchronous harmon- ics are found in all power systems and in the generator itself.Examples are static VAR controls,rectifiers,invert- ers,pot lines,high voltage dc trans- mission terminals,power transformers, and static adjustable speed fan drives. Harmonic Heating Induced heating in the generator rotor results from load unbalance as well as harmonics.The heating due to load unbalance is defined by calculating the negative sequence current,I,,induced in the rotor.ANSI standards'(C50.13) require a specific capability for each unit (see section titled CONTINUOUS OPER- ATION WITH UNBALANCED ARMATURE CURRENT). The heating resulting from the harmonic currents can be calculated as an equiva- lent negative sequence current (T3509)asshowninequation(2). GEK-75511B NOTE:The sum of the I7 due to load unbalance and the I due to har- monics should not exceed the nega- tive sequence capability of the generatore The following equation considers the effects of harmonics taken in pairs.m is a series of positive integers and (3m -1)(3m +1)represents the series of harmonic pairs.When m =1,the pairs are the second and fourth harmonic currents;when m =2,the pairs are the fifth and seventh harmonic currents, etc. 23m)1/2T2EQ=J=(22)(¢an-1)*F(a+1}2.(2) where: m =a series of integers defining harmonic pairs (3m-1)(3m+1)the harmonic pairs T(3m-1)=lowest-order harmoniccurrentofthehar- monic pair in peu. =highest-order harmon- ic current of the harmonic pair in Pelle T(3m+1) Torsional Vibration The interaction of the flux fields of each harmonic current with the air gap flux produces torques on the tur- bine-generator shaft system.Harmonic sources produce many harmonics of inter- est,but also routinely include filters for many high frequencies.As a practi- cal matter,the fifth and seventh har-= monic currents become the harmonics of interest.Each produces a continuous torsional stimulus on the generator O rotor at the sixth harmonic frequency. ' Pie maa Li lat ll a a yt i Mn RS ean SB Maalieowidteot 8 ken obs Ake otare a hes eer 2 E The oscillating torque has the potential for stimulating the turbine-generator in complex,coupled modes of vibration that involve torsional oscillations of the rotor elements and flexing of the tur- bine buckets.If such a.coupled mode of mechanical vibration exists close to the frequency of electrical stimulus,then high,resonant,mechanical responses may be developed which could result in high cycle fatigue duty to the shafts and turbine buckets. Current industry state of the art does not permit calculation with a high degree of confidence of natural torsion- al frequencies in the sixth harmonic supersynchronous regimee However,there are a number of turbine-generators cur- rently operating at or near sources of significant harmonics.In no case has any damage been observed which can be correlated with a torsional stimulus. The probability of damage is a function of (a)the coincidence of the stimulat- ing frequency (360 hertz on 60 hertz systems)and the torsional natural res- onance frequency (which cannot be ac- curately calculated);and (b)the magni- tude of the torsional stimulus. It must be noted that the generator also contributes some fifth and seventh harmonic current,which is typically 0.3 percent (0.003 peu.)for the arithmetic sum of Is and Ij,and this will appear along with the harmonics contributed by other sources. Measurements have been taken at a small number of stations,and values for the sum of Is and I7 have ranged from about 0.2 percent to over 2 percent. The lower value could possibly consume some turbine-generator component fatigue life if the rotor systems were stimu- lated very close to or on resonance. However,a unit which has been operating at the higher value appears to have sustained no damage,presumably because it was not operating near resonance. p) » GEK-75511B The resonances are very sharp peaks with very narrow bandwidths and there- fore the likelihood of being on reson- ance is very small.It is desirable, nevertheless,to limit the fifth and seventh harmonic currents to values as low as practical,to minimize the risk of component fatigue failures. INSPECTION FOLLOWING A TRIPOUT If the generator is tripped off-the- line due to any of its protective de- vices,no attempt should be made to resynchronize before the cause of the tripout is determined. In many cases,special generator tests are recommended before resynchro- nization.For example,following a tripout due to the phase differential relays,both the armature and field windings should be meggered and other- wise inspected before attempting to resynchronize.e Contact the General Electric Company for specific instruc- tions. ABNORMAL OPERATING CONDITIONS Protection of the generator against most abnormal operating conditions should be accomplished with relays or functionally similar devices.The pro- tection recommended by the General Elec- tric Company is covered in detail in "Generator Protection",in this Tab. Some abnormal conditions which relate closely to generator operation are dis- cussed in the following paragraphs. GENERATORS SHOULD NOT BE LOADED BEYOND TRE CAPACITY OF THE MEASURING INSTRUMENTS UNDER ANY CIRCUMSTANCES. OPERATION WITH OVERLOAD The generator should not be operated at any loads above the nameplate capa- hates wnies ohm St iis Srlthts la "aca:Bisnis te ke Pe in a Me Na te te he te,Ce le bility even though its operating tem- perature rises may be below the guaran- teed maximum temperature rises and the water available for cooling the genera- tor may have a lower temperature than the maximum water temperature specified on the data sheet.The generator is de- signed to give long,relatively trouble- free life for continuous or intermittent operation at its rated output;overload- ing encroaches on the design margin built into the machine. With respect to overload operation, which often accompanies system disturb- ances,industry standards require that a generator be capable of carrying 130 percent of rated stator current for one minute,and 125 percent of rated field current for one minute.These over- loads,of course,result in higher-than- normal heat generation in the stator and field windings,and copper temperatures rise rapidly.The heat capacity,or thermal storage capability,of these windings will limit their total tempera- tures provided only short times are involved.However,the longer.such overloads persist,the greater is the likelihood of excessive temperatures with consequent damage to the generator. LOSS OF EXCITATION OPERATION OF A TURBINE=GENERATOR WITHOUT FIELD EXCITATION WILL CAUSE EXCESSIVE HEATING.»The degree to which this heating will occur depends on several conditions,including the initial load on the generator,the manner in which field current is lost, and the manner in which the generator is connected to the system.If excitation is lost,the generator tends initially to overspeed and operates as an induction generator.This overspeed normally results in a reduction in load due to the characteristics of the turbine governor,an increase in armature current,possibly low voltage 9 .4 : .*.wots eo ve .2 ee2edieMoneeooeSeaneedEelcatete 4$ " 4 GENERAL ELECTRIC COMPANY LARGE STEAM TURBINE-GENERATOR DEPARTMENT SCHENECTADY,N.Y.12345 kindicates addition. sexi GENERAL@@ ELECTRIG 89 =' arSees .vg 5 tog rs :. .”2 Lo,.ed .;a .BF |merece oO leet Laat aE ae fe ltfaenie SO Ledehar sc ale inai sede,alba ane a el na Mont nadie scant elec cate RR haan im A da ah Sal Rome:9 a Dinca tke sent emma acti tam atninbbnnar nr tt e,=.= REV.2-13-81 GOLDEN VALLEY ELECTRIC ASSOCIATION INC. MOTOR CRITERIA GVEA approval is required for any motor greater than 10 HP on the GVEA system.If necessary,GVEA will do a motor study to determine detrimental effects to the GVEA system.It is the customer's reszonsibility to make changes in his equipment to correct detrimental effeccs on GVEA system which are caused by the equipment when they are discovered now or in the future.GVEA uses REA Bulletin 160-3 "Service to 'Induction Motors"and IEEE paper PCI 78-41 "Electric Utility Flicker Limitations"as a guide for the motor start evaluation.The customer must provide GVEA with the following data for the motor study:(this data is normally submitted with the load data information) 1)Plot Plan -showing physical layout and dimensions of the various equipment on tne customer's system. 2)One Line Diagram -showing electrical parameters of all equipment from the GVEA tap point to the motor terminals.This shall include the following: a)All conductor sizes and types. b)All transformer sizes,voltage,phases,and %impedance. c¢)All buss voltages,phases d)Fuse sizes and types e)Lengthof all conductor runs if not shown on the plot plan. 3)Motor information -The following data shall be submitted for all motors on the customer's systam. a)Type of service:number of starts per day,cyclic loading characteristics.- b)For multiple motors describe intended starting and operating practice.Show provisions to prevent simultaneous starting, if installed. c)Motor:type,HP size,code letter,voltage,phases,full load current,locked rotor current,motor starting equipment and characteristics. d)Other data which may be pertinent to the particular application. MOTCR STARTING Generally the motor starting inrush shall not produce a voltage change (flicker)of greater than 5%on the GVEA system at a location where other customers will be affected. This location is normally considered to be where the customer's system ties to GVEA primary lines.Figure 1 is a general guide showing *voltage change for various rates of flicker,exact value allowed will be determined on a case by case basis. The %flicker value allowed is determined based on the number of consumers affected, and the type of feeder being served from and number of starts per day.The %voltage flicker is calculated using GVEA impedance values and values from the final design of the customer's system and motor starting parameters.If across-the-line starting Produces greater than the allowed voltage change,starting equipment must be in Stalled to limit the inrush to produce less than the allowed change. Where the customer's system tiles directly to GVEA's transmission line rather than the distribution line the %flicker value may be adjusted depending on the location.I£ more than one motor is involved and no provisions have been made to prevent the Motors from starting simultaneously,the sum of all the motors will be used for the Calculatceon. Page 1 of 2 For the customer's engineer's preliminary calculations,GVEA will provide the MVA fault current available at the tap to the customer's system,once the service location has been determined.However,final GVEA approval will not be given until the study « has been done and the results show that GVEA requirements are met. For extremely large motors GVEA may require special starting procedures.The special procedures might include a requirement that the motor start be coordinated with GVEA and clearance given for the start by GVEA.Future detrimental effects to the GVEA system caused by the motor starting will be required to be corrected by the customer fo service to continue. MOTOR RUNVING 7s Cyclic flicker resulting from periodic voltage fluctuations caused by the operation of a motor driving a varying load,are of concern to GVEA.Figure 1 is a general guide showing the %voltage change for various rates of flicker,exact values which. will be allowed are determined on a case by case basis.In addition to the voltage flicker,the cyclic loading of a motor may cause power swings which are detrimental to the GVEA system.The rate,magnitude,and duration of the power swings are factors wnich will be considered..Generally any power swing which is greater than 400 kW total,or causes a system frequency swing of greater than 0.03 HZ,will require corrective equipment.Operation of any equipment on the GVEA system which cause detrimental effects will be required to be corrected by the customer for service to continue.. . PERMISSTZLE FRICKE?OSItuITtTs (Gtyrrz) Il |8 --a7.55,7+l bi-+1=SN |' i \1 Pp)..° 33 6 Only one Nao Threshhold of Objection ' -service 6 ty affected iw |S 3 ytd Peet td =rn a |° Fat More than one h |Y awte4bLserviceaffecteds-= t 48 S L | &3.3%o-| SSS rs)i]-g 3 3 & Le ee |a bemea\|. 2 He .{ot we /Primary feeder -t IPN 2 serving many customers ”|tl / L |L \L | 1PEsi1 F |0 AY s .°7 a Nl N ns g Rinna wn 2 Rafi in "x NA PER ee DER HOUR "PER MINUTE Nl ER SECOND" i i \ RATE OF FLICKER FICNOR 4 . Page 2 of 2 DISPATCH/SCHEDULING SUBCOMMITTEE MINUTES 9:00 A.M.-April 16,1985 AT MUNICIPAL LIGHT AND POWER Attendance:E.Jameson Matanuska Electric Association George Bowen Municipal Light &Power Ken Bradley Consultant Afzal H.Khan Alaska Power Authority Charles Parrish Morrison/Knuden Marvin Riddle Golden Valley Electric Association Larry Walls Chugach Electric Association Ray L.Duncan Chugach Electric Association Doug Hall Municipal Light &Power Mike Massin Municipal Light &Power Pete Smithson Municipal Light &Power Jerry Stevenson Municipal Light &Power John S.Cooley Municipal Light &Power Discussion with Morrison/Knudsen,APA and affected utilities detailed foundation of APA proposed start-up schedule and switching order. ML&P and CEA has concerns on how we handle billing for power used during start-up and special switching required to configure CEA's 138Kv International to Airport which presently networked at Port Worzonoff.If line relays all 138Kv system networked would relay. Discussed interim start-up for control CEA would regulate fre- quency,ML&P and GVEA tie line bias.ML&P uses Douglas Metering at tie line for system net.FMUS handled separately by GVEA. Need to address permanent solution for frequency control. Discussion on revenue metering calibration and sealing. Representive from each utility to witness when calibrated,sealed. RESERVE/LOAD SHED SUBCOMMITTEE 1:00 P.M.-April 16,1985 AT MUNICIPAL LIGHT &POWER Attendance:Ray L.Duncan Larry Walls Ed Morris Howard Thacke Hank Nikkels Ken Bradley Doug Hall Marvin Riddle Bob Orr Larry Hembree Chugach Electric Association Chugach Electric Association Alaska Power Authority Alaska Power Authority Municipal Light &Power Consultant Municipal Light &Power Golden Valley Electric Association Golden Valley Electric Association Municipal Light &Power The Reserve/Load Shed Subcommittee met and discussed the defina- tion of Spinning and Operating Reserves as defined by Addendum #1 and Exhibit A of the Intertie Operating Agreement. It was a unanimous decision of the Subcommittee that the wording in B2.2.2(b)immediately supplying through action of automatic govenor controls.This is interpreted as saying the Spinning Reserve is that amount that is connected to the bus and ready to accept load by automatic governor controls (machine droop)or a higher level of control. B-2.2.3 Section B-2.3 B-2.3.1 Section B-2.4 Generating unit capability for Operating Reservesshallbedeterminedbythefollowingcriteria: a.It shall not be less than the Inad on the machine at any particular time nor greaterthan(b)below. b.It shall not exceed that maximum amount of lead (I?)that the unit is capable ofcontinuouslysupplyingforatwo-hour period,.or immediately supplving through action_o#.automatic govertior Controls,Code 7 -Drere TonedThecriteriaspecifiedinthissection"may bemodifiedcrchangedbytheOperatingCommittee. Utility Participent's Allocation of Operating Reserves The Operating Reserve Obligation of a UtilityParticipantshallbethatpercentageoftheTotalOperatingReserveObligationdeterminedbv_theOperatingCommitteeinaccerdancewiththe followirg formula based on the capability of largest generating unit contingency in cperationateachUtilityParticipant. B-2.3.1.1 Individual Utility Participant ReserveAllocationFormula IOR =TOR x Us/Ut fooOooulIndividual Utility Participant Operating Reserve Requirement ryoOod"Total Operating Keserve Requirement Us =A Utility Participant largest on-line generation unit capabiliry Ut itSum of each Utility Participant's Tg Operating Reserve Calculaticn System Spinning Reserve shall be calculated at anygiveninstantasthedifferencebetweenthesumofthenetcapabilityofallgeneratingunitsonline in the respective system and the integrated Systems Demand of the svstem involved. Addendum Mo.1 -2 of Il. III. IV. VI. VII. VIII. ANCHORAGE FAIRBANKS INTERTIE -OPERATING COMMITTEE - SUBCOMMITTEES Relay/Protection Subcommittee *John Marshall, Jim Hall, Larry Hembree, Afzal Khan, Handbook/Procedures Subcommittee *Sam Matthews Mike Massin, Bob Orr, Stan Sieczkowski, Machines/Rating Subcommittee Jay Troy, Hank Nikkels, **vacant chairmanship Alan Martin Reserves/Load Shed Subcommittee *Ray Duncan, Marvin Riddle, Howard Thacke, Hank Nikkels, Larry Hembree, Keith Sworts, S.V.S.Evaluation Subcommittee Afzal Khan, John Marshall, **vacant chairmanship Dave Shaeffer, S.C.A.D.A/Metering/Communications *Bob Orr, Subcommittee Hank Nikkels, Afzal Khan, Jim Hall, Ray Duncan, Marvin Riddle, Robert Day, Alan Martin, Dispatch/Scheduling Subcommittee *Ray Duncan, Hank Nikkels, Marvin Riddle, Alan Martin, Budget Subcommittee *Bob Orr, John Marshall Mike Massin, *Chairman Revised 2/25/85 Sisal lle cleatll eee deed a ee ae Frank Abbegg III, eee RES COSTS CIOS?SNES BEEOO ROTI MOSS B PS SCCe Oren: CEA MEA ML&P APA HEA ML&P GVEA APA Ad. CEA ML&P GVEA FMUS CEA GVEA APA MLE&P ML&P FMUS APA CEA G.C.A. GVEA ML&P APA MEA CEA GVEA ML&P FMUS CEA ML&P GVEA FMUS GVEA CEA ML&P ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE SUBCOMMITTEES Page 2 X.Load/Resources Subcommittee *John Marshall, Bob Orr, Mike Massin, XI.Dispatcher/Training Subcommittee *Marvin Riddle, Ray Duncan, Hank Nikkels, Vacant Ernie Jamieson, Stan Sieczkowski, Alan Martin, Larry Wolf, John Aspnes, XII.Reliability/Criteria Subcommittee *Sam Matthews, Afzal Khan, Larry Colp, Larry Hembree, John Marshall, Jim Hall, Harry Beck, Steve Haagenson, *Chairman Revised 2/25/85 CEA GVEA ML&P GVEA. CEA ML&P HEA MEA APA (Fed) FMUS APA (State) U.A.F. HEA APA FMUS ML&P CEA MEA U.A.F. GVEA as& : i .So,.oadinsheAGSSe2atnteeaaaaelallniMakLillltaSaiadaoaaeshHearntnasantumbibechisd OAnchorage "Fairbanks Intertie Uperating Committee MINUTES January 18,1985 Anchorage,Ak. ATTENDANCE:Mike Massin Municipal Light &Power Mike Yerkes Alaska Power Authority James Hall Matanuska Electric Assn. Stan Sieczkowski Alaska Power Administration John Marshall Chugach Electric Association Dan Rice Gilbert Commonwealth Robert Day Municipal Light &Power Bob Orr Golden Valley Electric Assn. Marvin Riddle Golden Valley Electric Assn.Ram Krishna Morrision-Knudsen - Larry Colp Fairbanks Municipal Utilities System Larry Wolf Alaska Power Authority Afzalh Kahn ,Alaska Power Authority Michael Ridge Alaska Div.of Telecommunications The meeting was called to order by Chairman Orr at 9:10 A.M.in the Municipal Light &Power conference room. Larry Colp motioned that the minutes be adopted as written.Bob Orr seconded the motion.The motion was approved unanimously. Mike Massin then motioned to adopt the agenda as written.John Marshall seconded the motion.The motion was approved unanimously.. Under Committee Correspondence and Reports,Bob Orr read a letter he received from Eric Haemer of Chugach Electric Assn.,advising the Operating Committee that John Spence from CEA would be replaced on the Opérating Committee Machines/Ratings Subcommittee by Mr.Jay Troy.Bob Orr then also noted that Steve Haagenson of Golden Valley Electric Assn.would be the GVEA representative to the Operating Committee Reliability/Criteria Subcommittee.He further requested that Mr.Haagenson's name appear on the Subcommitte- listing as well as the change from Mr.Spence to Mr.Troy on theMachines/Ratings Subcommittee. Bob Orr then reported that the SCADA/Metering/Communications Subcommittee did not meet on Tuesday,January 15,1985 as was ori- ginally scheduled.Bob did report that Municipal Light &Power, Golden Valley Electric Assn.,Systems Controls Inc.and Landis & Gyr had met in California the previous week to go over theAnchorage/Fairbanks Intertie Data Link Requirements.He noted that the group gathering in California also reviewed the December 31,1984 draft of the Anchorage/Fairbanks Intertie Data Link requirements (see attachments to these minutes).Bob furnished the Operating Committee with minutes of the January 8,1985meetingwhichwasheldinCalifornia(see attached).Bob also noted that the Alaska Power Authority,through Gilbert-Commonwealth, ee are O [e)January 18,1985 AFIOC Minutes Page 2 has furnished a draft called "Acceptance and Functional Test PlanforCommunicationFacilities"to all of the concerned utilities(this is also attached to the minutes). The Reliability/Criteria Subcommittee met on Wednesday,January 16,1985 and John Marshall reported on the subcommittee activi- ties.John noted that the subcommittee had looked at five (5) specific cases for dynamics stability studies to be performed by Gilbert-Commonwealth.John indicated the consultant's study sum- Maries don't reflect the generating capacity of the Eklutna (Alaska Power Administration)power station.John also discussed the various other areas that the subcommittee had reviewed.He noted that discussions centered around "steady-state"conditions and the subcommittee will also want to look at "transient"con- ditions. Marvin Riddle then reported on the activities of the Dispatch/Scheduling Subcommittee which also met on January 16, 1985.He noted that the subcommittee had reviewed for the second time,the Anchorage/Fairbanks Intertie Operators Manual.He reported that the Dispatch/Scheduling Subcommittee is recommending that the full Operating Committee adopt the North American Electric Reliability Counsel "NERC"guide No.10 and the NERC Control Performance Criteria.He also reported that Municipal Light &Power has indicated they will be installing a Dunstan Controller for schedule and frequency control.Marvin also fur- nished the Operating Committee with the response to comments and questions on the Anchorage/Fairbanks Intertie Operator Procedures Manual (not attached to these minutes).It is requested that each of the utilities provide any additonal comments they have on this summary to Gilbert-Commonwealth,attention Dan Rice. Mike Yerkes provided a status update on the intertie project.He indicated that the Alaska Power Authority was looking for comple- tion of the Intertie by the first week of March,1985.Regarding the failed Westinghouse transformer at Goldhill,Mike noted that Westinghouse plans to send the transformer back to St.Louis, Missouri for repairs.Although it is tentative,the transformer is expected to be back at Goldhill and retested by August 16, 1985.Bob Orr noted that Westinghouse had supervised the initial installation of the transformer at Goldhill.Regarding the SVS, General Electric has indicated that the SVS system at the Healy Power Station cannot be energized with the Healy power station on line.Mike reported that during the period when the Goldhill transformer is being repaired,Intertie operation would have to be on a reduced capacity basis through the smaller Golden Valley Electric Assn.transformer.With the Healy Power Station on line, the Intertie transfer would be limited to 15 megawatts.With the Healy power station out of service,the intertie capacity could be40megawatts.Mike also furnished the Operating Committee with a copy of the Gilbert-Commonwealth report to the Alaska Power Authority on the Goldhill transformer problem. (eoJanuary 18,1985 AFICO Minutes Page 3 John Marshall then reported that Chugach Electric Assn.would also be conducting a considerable amount of construction and rebuildingworkwhichwouldhaveanimpactontheAnchorage/Fairbanks Intertie during the current year.He noted that the existing138KVPointMcKenzietoTeelandSubstationtransmissionline is scheduled for re-installation for 230KV operation and this work is to be conducted during the summer of 1985.John also reported that CEA is planning to reconstruct the high voltage Bus at theTeelandSubstationfornewoperationasa'230KV 'ring Bus.It'was also reported by John that included in the Teeland reconstruction would be a rebuild of the 115KV portion of the switchyard into a 4 bay arrangement with a transfer Bus capability.This work would also take place in 1985 and John reported that the entire Teeland Substation would most likely be out of service during the construction.Mike Yerkes then reported that the Alaska Power Authority had finished the draft SCADA agreement with Golden Valley Electric Assn.and that the agreement was now ready to be signed.He also noted that the Alaska Power Authority will senda copy of the GVEA/APA/SCADA agreement to ML&P. There were no visitors present at today's meeting;however,Mr. Michael Ridge from the Alaska Division of Telecommunications was present for purposes of providing the Operating Committee with a status report on the work of the Division of Telecommunications as it relates to the communication facilities required for the Anchorage/Fairbanks Intertie. At this point in the meeting,Mike Yerkes then proceeded to intro- duce Michael Ridge of DIVCOM and prefaced Mike's report by saying that DIVCOM has done quite a bit of work so far on the com- munications link required between Anchorage and Fairbanks.Mike Ridge reported that a microwave interconnect has been installed between site Summit and Chugach Electric Association's inter- national station,between site Summit and Municipal Light &Power and between Goldhill and Esterdome.He reported that DIVCOM has made application to the FCC for Municipal Light &Power and also that the equipment needed for Municipal Light &Power is expected to arrive in approximately three (3)weeks.He reported that the Cantwell tap is almost ready to be tied into the DIVCOM system. He noted that DIVCOM will provide Municipal Light &Power and Golden Valley Electric Assn.with technical assistance duringstartupandtesting.He also noted that DIVCOM is pursuing a backup microwave route between Anchorage and Fairbanks which will eventually run from Anchorage to Glennallen to Tok to Delta and then to Fairbanks.This is expected to be in place in approxima-tely a year's time. January 18,1985 AFIOC Minutes Page 4 Chairman Orr,with the full and unanimous concurrence of the Operating Committee,recommended that the Intertie OperatingCommittee's Secretary draft a letter to Lisa Rudd,Commissioner of Administration expressing the Operating Committee's appreciation for the work being conducted by Mr.Ridge and his Associates. The Operating Committee had no old business to conduct at today's meeting. Turning to new business,the Operating Committee recessed into a work session at 11:15 A.M.At the outset of the work session,the Operating Committee elected to waiver a lunch recess and agreed to complete today's meeting before adjourning for a lunch. Turning to a discussion on Anchorage/Fairbanks Intertie Utilization and Scheduling,the Intertie Operating Committee discussed a need for the SCADA/Metering/Communications and the Dispatch/Scheduling Subcommittees to pursue procedures for quotes and acceptances for power and energy sales as they interface withthenorthernandsoutherncontrollers. Turning to SCADA/Metering/Communications,Mike Yerkes reported that the Alaska Power Authority considers the Gilbert-Commonwealth Anchorage/Fairbanks Intertie Data Link Requirements document dated December 31,1984 to be in its final form.Gilbert- Commonwealth will advise the Alaska Power Authority on the Utilities conformance to the Data Link Requirements.The Operating Committee then discussed CEA's interface arrangements with the DECNET system.Mike Yerkes requested that ML&P and CEA keep Gilbert-Commonwealth appraised of the ML&P and CEA SCADA/DECNET development.It was reported by Bob Orr that the ML&P and GVEA vendors were meeting on January 15,1985 and that they would be furnishing a report to the utilities on January 29, 1985 and that there would be a requirement for the SCADA/Metering/ Communications Subcommittee to review the vendor recommendations. The Operating Committee then briefly discussed Dispatch/Scheduling and Mike Massin requested that the Alaska Power Administration (Mr.Sieczkowski)be included in the scheduling work being con- ducted by this subcommittee.Marvin Riddle again reiterated that the Dispatch/Scheduling Subcommittee had recommended that the full Operating Committee adopt NERC guide #10 and NERC Control Performance Criteria. Turning to the Reliability/Criteria Subcommittee work,John Marshall again indicated that Gilbert-Commonwealth would come up with revised "steady state"case studies which will include the Eklutna Power Plant and that they will also include some "transient"cases as part of their work.Gilbert-Commonwealth will also look into the Northern Railbelt utilities use of load- shed to meet reserves. Oone ee January 18,1985 AFIOC Minutes Page 5 Dan Rice also noted that Gilbert-Commonwealth will also look intotheMatanuskaElectricAssn./Eklutna project 115KV line.Bob Orr'also indicated that he would like to see Gilbert-Commonwealth look into A.C.E.as part of the loadshedding. Mike Yerkes also reported that the Alaska Power Authority ispursuingwhatisgoingtobeneededtoinsurethatspareparts fortheIntertieprojectarestoredatthevarioussubstationsitesor as close as possible.He noted that they are still in the processoflookingforsuitablestoragesitingforsparetransmission towers.Finally,he noted the Alaska Power Authority is alsoinventoryingallthesparepartsfromthevariouscontracts. The Operating Committee then came out of work session and pro- ceeded into the formal Operating Committee Actions/Recommendations portion of the meeting. Bob Orr motioned that the full Operating Committee adopt the December 31,1984 Anchorage/Fairbanks Intertie Data Link Requirements which were revised by Gilbert-Commonwealth and reviewed by the SCADA/Metering/Communications Subcommittee.Mike Yerkes seconded the motion;the motion was approved unanimously. Marvin Riddle then motioned for the full Operating Committee to adopt NERC guideline,No.10 and NERC Control Performance Criteria subject to each of the guides having headings which reflect the Anchorage/Fairbanks Intertie and that they also provide for a revision and approval dating feature.Mike Yerkes seconded the motion;the motion was approved unanimously (see attached NERC guide No.10 and NERC Control Performance Criteria). Bob Orr then reported that Mr.Sam Matthews from Homer Electric Assn.had taken ill and was currently at Humana Hospital.Bob requested that the Intertie Operating Committee send a get-well card to Sam. Election of new officers will take place during the March,1985 Operating Committee meeting.As such,a nominating committee will be selected at the February,1985 meeting. Turning to subcommittee assignments,Chairman Orr directed that the SCADA/Metering/Communications Subcommittee meet jointly with the Scheduling/Dispatch Subcommittee to review the ML&P/GVEA vendor proposals on SCADA/DECNET which are to be received approxi- mately January 29,1985 and that they further work on scheduling formats and procedures with emphasis being placed on interfacing"with the Intertie Data Link.THE JOINT SCADA/METERING/ COMMUNICATIONS-SCHEDULING/DISPATCH MEETING WILL BE HELD AT 9:00 A.M.ON TUESDAY,FEBRUARY 5,1985 IN THE OPERATIONS DIVISION TRAINING ROOM AT MUNICIPAL &POWER.This training room is located directly across the street from the ML&P Headquarters building. Chairman Orr then directed the Reliability/Criteria Subcommittee January 18,1985 AFIOC Minutes Page 6 to meet and review the draft of the studies to be conducted by Gilbert-Commonwealth under the direction of Dr.Prabhakara.THE RELIABILITY/CRITERIA SUBCOMMITTEE IS TO MEET AT THE CHUGACH ELECTRIC ASSOCIATION ENGINEERING CONFERENCE ROOM AT 9:00 AM ON TUESDAY,FEBRUARY 12,1985. THE NEXT REGULARLY SCHEDULED MEETING OF THE ANCHORAGE/FAIRBANKS INTERTIE OPERATING COMMITTEE WILL BE AT 9:00 A.M.ON THURSDAY, FEBRUARY 14,1985 IN THE OPERATIONS TRAINING DIVISION OF MUNICIPAL LIGHT AND POWER AT 1201 E.FIRST AVENUE,ANCHORAGE,ALASKA, PLEASE NOTE,THAT THIS DATE HAS BEEN CHANGED SINCE THE COMMITTEE MET ON JANUARY 17,1985.THE MEETING WAS PREVIOUSLY SCHEDULED FOR WEDNESDAY,THE DAY BEFORE. Larry Colp then motioned for the meeting to adjourn.John Marshall seconded the motion.The Operating Committee then unani- mously approved the motion to adjourn at 12:30 P.M. Respectfully submitted,WpLieuMikeMassin-Secretary Anchorage/Fairbanks Intertie Operating Committee Attachments:1)February Meeting Agenda 2)Letter from Eric Haemer 3)Revised Anchorage/Fairbanks Operating Committee Subcommittee Listing 4)Gilbert-Commonwealth letter on Interim Intertie Operations 5)Gilbert-Commonwealth Anchorage/Fairbanks Intertie Acceptance and functional Test Plan for Com- munications Facilities 6)Minutes from ML&P/GVEA Vendor Meeting in California 7)Dispatch/Scheduling Subcommittee Minutes from 1/16/85 8)Copies of adopted NERC Guide No.10 and NERC Control Performance Guides.(Distribution only to Operating Committee Members) [eAnchorage 'Fairbanks Intertie Uperating Committee -AGENDA- _ Thursday,February 14,1985 Begin at 9:00 A.M. I.Adoption of prior meeting minutes II.Approval/modification of agenda III.Committee correspondence and reports A.SCADA/Metering/Communications Subcommittee B.Reliability/Criteria Subcommittee 7 C.Dispatch/Scheduling Subcommittee D.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.G.E./G.C.A.S.V.S.Presentation C.SCADA/Metering/Communications D.Dispatch/Scheduling E.°Reliability/Criteria F.Other VII.Formal Operating Committee actions/recommendations VIIL.Subcommittee assignments IX.Set agenda for next meeting X.Adjournment Adjourn by 4:30 P.M. Meeting location:Municipal Light &Power (Operations Training Room) 1200 First Avenue Anchorage,Alaska (907)279-7671 [eO ANCHORAGE FAIRBANKS INTERTIE -OPERATING COMMITTEE - SUBCOMMITTEES I.Relay/Protection Subcommittee II.Handbook/Procedures Subcommittee III.Machines/Rating Subcommittee **vacant chairmanship IV.Reserves/Load Shed Subcommittee Vv.S.V.S.Evaluation Subcommittee VI.S.C.A.D.A/Metering/Communications Subcommittee VII.Dispatch/Scheduling Subcommittee VIII.Budget Subcommittee *Chairman Revised 1/17/85 *John Marshall, Jim Hall, Larry Hembree, Vacant *Sam Mathews Mike Massin, Bob Orr, Stan Sieczkowski, Jay Troy Hank Nikkels Frank Abbegg III, Alan Martin *Ray Duncan, Marvin Riddle, Vacant Hank Nikkels, Larry Hembree, Keith Sworts, *Vacant John Marshall, Dave Shaefter, *Bob Orr, Hank Nikkels, Vacant Jim Hall, Ray Duncan, Marvin Riddle, Robert Day, Alan Martin, *Ray Duncan, Hank Nikkels, Marvin Riddle, Alan Martin, *Bob Orr, John Marshall Mike Massin, CEA MEA ML&P APA HEA ML&P GVEA APA Ad. CEA 'ML&P GVEA FMUS CEA GVEA APA ML&P ML&P FMUS APA CEA G.C.A. GVEA ML&P APA MEA CEA GVEA ML&P FMUS CEA ML&P GVEA FMUS GVEA CEA ML&P O O ANCHORAGE FAIRBANKS INTERTIE OPERATING COMMITTEE SUBCOMMITTEES-Page 2 X.Load/Resources Subcommittee XI.Dispatcher/Training Subcommittee XII.Reliability/Criteria Subcommittee *Chairman Revised 1/17/85 *John Marshall, Bob Orr, Mike Massin, *Marvin Riddle Ray Duncan Hank Nikkels Vacant Ernie Jamieson Stan Sieczkowski Alan Martin Larry Wolf John Aspnes *Sam Mathews Vacant Larry Colp Larry Hembree John Marshall Jim Hall Harry Beck Steve Haagenson CEA GVEA ML&P GVEA CEA ML&P HEA MEA APA (Fed) FMUS APA (State) "UA.F. HEA APA FMUS ML&P CEA MEA UAF GVEA g,>Gil b ert /Comm onwea It h engineers/consultante/architects - GILBERT/COMMONWEALTH ING,OF MICHIGAN,209 E.Washington Avenue,Jackson,Mt 49201/Tal.817 786-3000 January 15,1985 APAI-20561 Mr.David R,Eberle Alaska Power Authority 334 West 5th Avenue Anchorage,AK 9950} Dear Mr.Eberle: SUBJECT:ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE INTERIM CAPABILITY OF THE INTERTIE The attached memorandum responds to APA's questions concerning the possible interim transfer capability of the intertie withoutthenewtransformeratGoldHil}. ject Manager LGM/1drv cc:Mr,T.S.Small,w/a Mr,O.A.Rice,w/a ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE INTERIM CAPABILITY OF THE INTERTIE wee _ The purpose of this brief report 1s to discuss the reduction in the permissible power transfer on the Intertfie until the new 138 kV/69 kV transformer at Gold Hill is repaired and put back in-service,In the interim the existing stepdown transformer will be used. The existing transformer has a maxfmum capacity rating of 30 NVAR, Because of the limited Gold Hill transformer capacity,the Intertie power transfer in the interim should be based on; Peer =30 MW -Healy generation +Healy &Nenana Loads +Line Loss (Healy to Gold Hi11) Assuming Healy and Nenana loads and line losses to be about 10 MW and Healy generation of 25 MW;the maximum interim power transfer on the Intertie should be limited to about 15 MW (metered at Healy).When Healy generating unit is out of service,the power transfer could be up to 40 NW, Gold Hill]SVS is not considered essential to achieve these power transfer Tevels.However,nonavatlability of Gold Hill SVS imposes two important modifications to operating requirements until Gold Hi11 SVS becomes : avaflable.They are, a.The Intertie should be taken out of service whenever Teeland SVS is out of service.Otherwise,failure of Healy SVS and a second contingency such as load rejection may cause excessive overvoltages. b.When Healy SYS goes out of service,the Intertie should be automatically removed from service, Page1 of 2 FSP 01/15/85 2 'd Wiisl We have reviewed the possibility of connecting Gold Hil]SVS to the tertiary of the existing transformer.The existing transformer is rated at 30 NVAR,where as Gold Hill SVS reactor is rated at 38 MVAR (maximum). The tertiary of the existing transformer is rated at 12 kV,where as the SVS rated voltage is 13.8 kV.Even though the Gold Hill SVS may operate mostly in the +5 MVAR range at light load,we belfeve that it is inadvisable to connect the Gold Hill SVS to the tertiary of the existing transformer. Besides,it may not be feasible to start the Gold Hill SVS when connected to the tertiary of the existing transformer. Conclusions: 1.The transfer capability of the intertie 1s limited by the capacity rating of the existing Gold Hill transformer rather than the nonavailability of the Gold Hill SVS. 2.Gold Hill SVS cannot be connected to the tertiary of the existing transformer. 3.The interim power transfer to Fairbanks on the Intertie should be limited to about 15 MW with Healy generation and 40 MW without Healy generation. 4,In addition to limiting the Intertie power transfer two important changes in the operating procedures are recommended;namely, a.Whenever Teeland SYS is out of service,the Intertie should be taken out of service. b.Whenever Healy SVS goes out of service,the Intertie should be automatically removed from service. Page 2 of 2 FSP 01/15/85 .FonMaaa rgdRsGilbert/Commonwealth engineersandconsultants piilal pur GILBERT /COMMONWEALTH INC.OF MICHIGAN,209 E.Washington Avenue,Jackson,MI 49201 /Tel.517 788-3000 cd ? 7 aaja!wpe ewwJanuary8,1985 ev ans aS ows:as? 'awyMr.Marvin Riddle "'yi!Golden Valley Electric Association,Inc.,\T QanP.O.Box1249 go VFairbanks,AK 99707 UO - Dear Mr.Riddle: SUBJECT:ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE ACCEPTANCE AND FUNCTIONAL TEST PLAN FOR COMMUNICATIONS FACILITIES Enclosed is a copy of the subject Acceptance and Functional Test Plan, as revised to reflect the choice of AML&P as the Intertie operator on the Anchorage end. The plan also reflects the installation of a microwave link between theCEAandAML&P control centers (via Site Summit)by DIVCOM. Sincerely yours, e G.Miller,P.E. roject Manager TLH/slg Enclosure ce:A.Khan,APA Similar letters to:D.Eberle,APA M.Ridge,ADOT R.Duncan,CEA T.Wellman,CEA S.Haagenson,GVEA J.Hall,MEA M.Massin,AML&P 525 Lancaster Avenue,Reading,PA/Morgantown Road,Green Hills,Reading,PA 215 775-2600 209 East Washington Avenue,Jackson,Mi 517 768-3000 ACCEPTANCE AND FUNCTIONAL TEST PLAN COMMUNICATION FACILITIES FOR THE ANCHORAGE-FAIRBANKS INTERTIE ALASKA POWER AUTHORITY Prepared by: Gilbert/Commonwealth Ine.of Michigan 209 E.Washington Avenue Jackson,Michigan 49201 August 1,1984 January 8.1985 (Rev.) SECTION 1.0 2.0 3.0 4.0 5.0 Figure 3-A Figure 3-B Figure 3-C Figure 3-D Figure 3-E Figure 5 TABLE OF CONTENTS - TITLE INTRODUCTION PARTICIPANTS AND RESPONSIBILITIES EQUIPMENT AND SYSTEMS DESCRIPTION ACCEPTANCE TESTING,FUNCTIONAL OPERATION SCHEDULE DRAWINGS Communications Channel Diagram AML&P/APA/CEA/DIVCOM Communication Facilities and Interfaces Communication Facilities Cantwell Substation Communication Facilities Fairbanks Intertie | Communication Facilities Teeland Substation APA/CEA/GVEA/DIVCOM Communication Systems Schedule PAGE 1.0 ACCEPTANCE AND FUNCTIONAL TEST PLAN COMMUNICATIONS FACILITIES FOR THE ANCHORAGE-FPAIRBANKS INTERTIE INTRODUCTION Communication facilities for the Anchorage-Fairbanks Intertie,are being provided under contractual agreements with three different organizations, and these organizations will own and maintain all communications equipment. A description of the SCADA,telephone and protective relaying channels required for the Intertie operation,is given in Section 3.0. Performance tests on these communication channels will include: a)Measurement of S/N (signal to noise ratio)on each channel to be used. b)On SCADA channels only,measurement of BER (bit error rate). These tests are described in Section 4.0. Functional testing will include the operation of telephone equipment over the subject channels,test operation end-to-end,of the protective relaying modem units,and test operation when available,of the SCADA RTU's (remote terminal units),with their associated master control facility. Section 5.0 includes a system start-up schedule for all tests outlined above. 2.0 PARTICIPANTS AND RESPONSIBILITIES Organizations involved in the Intertie communications performance and functional testing will include the following: Alaska Power Authority (APA) Gilbert/Commonwealth (G/C) Alaska Division of Telecommunications (DIVCOM) Anchorage Municipal Light &Power (AML&P) Chugach Electrie Association (CEA) Golden Valley Electric Association (GVEA) Figure 3-A in Section 3.0,illustrates the channel terminal location,the functional use of each channel,and the organization responsible for conduct- ing the channel performance tests. Approval of performance and functional operations and tests,may require the witnessing of each test by APA or G/C personnel. 3.0 3.1 EQUIPMENT AND SYSTEMS DESCRIPTION Microwave Systems Application Three different microwave systems are used to carry the SCADA,telephone and protective relaying signals required for the operation of the Anchorage- Fairbanks Intertie. Channel utilization and the geographic application of these three systems is shown on Figure 3-A.Although each of these three systems carries many more channels of information than is shown here,Figure 3-A illustrates only those channels pertinent to the operation of the Intertie. a)The DIVCOM microwave system is used to carry information between three pairs of terminals as follows: -Between Douglas substation and the CEA control center at 5601 Minnesota Drive in Anchorage.This link will include separate channels for telephone,SCADA and protective relaying inform- ation.The protective relaying information is applicable only to a transmission line between Douglas and Teeland substations,so this information must be interconnected to a channel on the CEA microwave system at the Minnesota Drive terminal,to be carried on to Teeland substation via the CEA microwave system. -Between Cantwell substation and the GVEA control center at 758 Illinois Road in Fairbanks.This link will include separate channels for telephone and SCADA information. -Between the GVEA control center at 758 Illinois Road in Fairbanks,and the AML&P control center at 1200 East First Avenue in Anchorage.This link will carry telephone and SCADA information on separate channels.This microwave link presently b) c) terminates at the CEA control center at 5601 Minnesota Drive in Anchorage.The final portion of this link,between the Site Summit Repeater and AML&P control centers,will be a new microwave link provided by DIVCOM. On each of these three links,DIVCOM has set aside additional channel capacity,up to a total of 12 channels on each link,if additional channels should be required in the future. The GVEA microwave system is being used to carry SCADA information on separate channels,between both the Healy power plant and Gold Hill substation and their control center at 758 Illinois Road in Fairbanks. The CEA microwave system is being used to carry protective relaying information to Teeland substation.This protective relaying information is transferred from the DIVCOM microwave system at the terminal location at 5601 Minnesota Drive in Anchorage. 47)[ay _a:4 Mh)a.4 Zz a:<t =x:oz §§Ee 3 5 8 fy 3=ES wc fe)hy}<{uJ u)[e)"no >.una of 9 r DIVCOM SF 2 °wo Os ig *pivcom \.12.CH.AVAILABLE FOR v v ¢"v \INTERTIE (9 SPARE)GVEAefCEA,ff Co KF \>!CH.AVAILABLE FORANCHORAGE2INTERTIE(9 SPARE) SCADA CH»o 2400BPS (9-2409,,BP5.4 scapa TEL.&>0 vA Q--o--_4 TEL.2. 3.PROT.REL.°O e400 BPS,{]SCADA _3. TOTAL CH.CAPACITY (9 SPARE)a °QO TEL.4 PROT.REL. | rn O o 2400 BPS _,{[]SCADA 5. TEL.;a&O -o AN &o Y\.TEL.6. SCADA .[}0 2400 BPS __,q 12CH.AVAILABLE For{O 2400 srs o--{]SCADA 7. INTERTIE (9 SPARE)}9 6 A TEL.8 |DATA oO °o 9600 BPS ©[DATA 10 .DATA DO o o 9600 BPS o {]DATA HW. .TEL.&"&o o o "TEL.12. .TEL.A-H TEL.a-hO .DATA Ct--(]_-s ASSUME _=9600B8PS DATA SPEED MICROWAVE LINKS SHOWN ABOVE OWNED AND MAINTAINED BY: FIG.3-A DIVCOM ALASKA DEPARTMENT OF TELECOMMUNICATIONS CEA CHUGACH ELECTRIC ASSOCIATION ALASKA POWER AUTHORITY GVEA GOLDEN VALLEY ELECTRIC ASSOCIATION ANCHORAGE FAIRBANKS INTERTIE AML&P ANCHORAGE MUNICIPLE LIGHT &POWER COMMUNCATIONS CHANNEL DIAGRAM AML _&P CONTROL CENTER TO GLEN,ALPS, CEA CONTROL CENTER OOUGLAS SUBSTATION TOFAIRBANKS *==SITE l.DIVCOM TO SUPPLY MICROWAVE.LINK TEELANO,ETC, SUMMIT AND WIRING BETWEEN INTERFACE (SEE FIG,3-E)4 PANEL AND DIVCOM MULTIPLEX DIVCO ST 2.ALL REMAINING EQUIPMENT AND :REPEATER SITE ra WIRING IS C.E.A.SUPPLIED. 10 VYmeeemeteeyeeeeeee|AML &PRADIOiRADIO||RADIO RADIOTRTR|:T/R T/R af]cH"NOTE |i ofl cui li CH.83 #+-FROM TEELAND CH.*5 o TEL .=3]}scapa |:PROT.PROT. Pu I 28 1 RELAY RELAY 3)]cu.*2 3 CHM2 |CH.*6 t CH."6SCADA!Ter.|!TEL.>|TEL CH"3 |(ae |!%ei PROT TRANSDUCERS °fa)CH."6 j}«CH *7 --e|CH *7"d Laevay TTT !351 TEL |!SCADA --|SCADA --ivy)*#DIVCOM |!wi ||CHAT !es CEA.EQUIPMENT.1 TEL -_-1 TEL.EQUIPMENT [--*I |swiTcH TEL ,CH.*10 ||CH.#15 |rev.||DATA |;eeINTERFACERINGERI=q CH*II 1 CH ieRTUPANELieS4pata|!AML a P[* i NOTE |"oe all DATA |:---CH #12 [5|}DIYCOMtHTJ7JTEL.)I o TEL.|I EQUIPMEN :x :EQUIPMENT-i}wmrsce dioica t2 (Penal)were°TELPROT|F HtRELAYijot-3a é CH.#15 ||TEELANO po EMS!rev, i CH "i6 iLCEATOSUPPLYRTUANDTELEPHONEEQUIPMENTANDALLDATA| WIRING INTO AND OUT OF INTERFACE PANEL.l SCADA 9 |!2.DIVCOM TO SUPPLY MICROWAVE LINK AND WIRING BETWEEN |SPARE ||SCADA TEL.CE»INTERFACE PANEL AND DIVCOM MULTIPLEX EQUIPMENT.=j |CUPMENT oveom i EQUIPMENT SWITCH TEL 3.APA TO SUPPLY ALL OTHER EQUIPMENT AND WIRING.EQUIPMENT:i 1200_EAST FIRST AVE. i i 5601 MINNESOTA DR. Note:Channef numbers given for coordination with Figure 3-A ONLY. fe oa oe ee ee ee te me mec emcee cess msec seri mm lame m eens msm smetm can, ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIEAML.&P/APA/CEA/DIVCOM Communication Facilities and Interfaces DATE:3-20-84 REVISED i-4-as/ill FIGIIRE %-A TO GVEA --Z_MOBILE UNITS GVEA _RADIO a TRANSDUCERS INTERFACE ' PARNELL rtu|7 J?TE: CANTWELL SUBSTATION DIVCOM TO SUPPLY CABLE AND TERMINATION "AT INTERFACE PANEL AND MULTIPLEX EQUIPMENT, APA TO PROVIDE RTU,TRANSDUCERS,TELEPHONE AND INTERFACE PANEL AND ALL WIRING. GVEA TO PROVIDE ALL UHF RADIO EQUIPMENT AND WIRING TO INTERFACE PANEL. FAIRBANKS ---y ADOT TO CANTWELL MAINTENANCE FACILITY a DIVCOM CABLE ANCHORAGE RADIO TR (____+ +-|seaoa CW.7GVEA emmaenannemesaan| ---- CHB GVEA TELEPH -- ---$-pr CHAN GVEA UHP ---__» XK . CH¥hsGVEA URE Ss | SPart!a-h DIVCOM NIC ROWAVE REINDEER MOUNTAIN \.Note:Channel numbers given for coordination with Figure 3-A ONLY. ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE Communication Facilities Cantwell Substation DATE:3-21 '84 REV.I-8-85 FIGURE 3-C aDIVCOM |REPEATERFy,CANTWELLANDANCHORAGE CNRADIO T/R CH.*7 CANTWELL SCADA CH.*8 CANTWELL TEL. ESTER DOME SITE FAIRBANKS l i l I I I l i I CH,*10 AML.&P|DATA |-AM.a Pp I I | l I | I ! | I ! DATA CH.#12 "|AML @P TEL. 9 SPARE TO AML &P CH.N =i CANTWELLINTERFACEUHF [CH NaFANELCANTWELLimUHF DIVCOM MICROWAVE 1.BIVCOM TO PROVIDE ALL WIRING BETWEEN INTERFACE PANEL AND MULTIPLEX EQUIPMENT. GVEA CONTROL CENTER FAIRBANKS Note:channel numbers given for coordination with Figure 3-A ALASKA POWER AUTHORITY ANCHORAGE-FAIRBANKS INTERTIE Communication Facilities Fairbanks Intertie DATE:7:26:84 REV.|-'8-85 FIGURE 3-D TO GLEN ALPS-CEA.CONTROL CENTER < AML &P CONTROL CENTER -5 RADIO T/R NOTE |CH.#5 |PROT TO DOUGLAS ss RELAY |.CEA.TO SUPPLY MICROWAVE LINK AND ALL WIRING VIA GLEN ALPS -42 :CH.#6BETWEENINTERFACEPANELANDMULTIPLEXmrTELEQUIPMENT.= 2,AML &P TO SUPPLY RTU AND TELEPHONE TRANSDUCERS CHS EQUIPMENT AND ALL WIRING BETWEEN INTERFACE -=|SCADA PANEL AND THIS EQUIPMENT.-CEA 3,APA TO SUPPLY ALL OTHER EQUIPMENT AND vidy FOUIPMENTWIRING.---____- TEL.k-RINGER >INTERFACEPANEL =|RTU NOTEtw2 TEL.ee L__ PROT. ”bOuSLASTEELANDSUBSTATIONL Note:Channel numbers given for coordination with Figure 3-A ALASKA POWER AUTHORITYONLY. | ANCHORAGE-FAIRBANKS INTERTIE Communication Facilities DATE:1-4-85/@.+FIGURE 3-E 4.0 4.1 4.2 ACCEPTANCE TESTING,FUNCTIONAL OPERATION Channel Performance Tests Although APA has contractual agreements with each of three microwave system operators to provide the communication channels described in Section 3.0,end-to-end performance tests will be made on each channel shown in Figure 3-A.These performance tests are normally completed by the microwave system operator during final system installation.These perform- ance tests,as described below,will be either witnessed by APA or G/C personnel,or a certified copy of the test results will be submitted to APA for review.End-to-end performance test requirements are: a)Signal to Noise Ratio (S/N)-All channels are to provide a S/N test result of 45 dB or better.This applies to all SCADA,telephone and protective relaying channels. b)Bit Error Rate (BER)-Using a suitable digital transmission test set, each SCADA channel is to be tested end-to-end at the digital bit speed shown on Figure 3-A.Over a 15 minute test period,the BER is to be equal to or better than 1 x 1079, Functional Operation Tests Following installation of all channel termination equipment,including but not limited to telephone instruments,protective relaying modems,and SCADA system remote terminal units,operational tests will be conducted end-to-end using these terminating equipments.All equipment will operate in a normal manner and transmit and receive all functional signals.These functional tests will be witnessed by APA or G/C personnel,or a certified copy of the test results will be submitted to APA for review. 5.0 SCHEDULE Figure 5 is a condensed version of the SCADA and Communication Projects Schedule.This condensed version clearly illustrates those intervals during which the communication channel performance tests and also when the functional operation tests ean be conducted. 7,6 9,a a 8 () COMM _INSTALL olEST9GVEAINTERIMSCADAINSTALLATEST.«OPERATIONAL 9 HEALY -GOLDHILL SCADA_INSTALL TEST-RTU AND MASTER STATION $2,GVER-SCADA|7£aT (OPERl(2)| (l)(2)|(2 1 (2) Diveom ¢COMM TEST OPERATIONAL_.TEST }TEST _4TESTh OPERATIONAL?DOUGLAS-CEA-TEELAND na'SCADA,TELEPHONE, '/ PROTECTNE RELAYINGCOMM|TEST OPERRTIONAL 7cen[|THE ;CANTWELL”EVER :SCADA _,JEST all INSTALL”RTU_AND MASTER5MV GVEA -AML £P_CONTROL CENTERSSCADA,TELEPHONE NOTES: ()END TO END PEKFORMANCE TEST PERIOD (2 FUNCTIONAL OPEKATIONAL TEST FEKIOD (3)TRANSFER FROM INTERIM SCADA TO PERMANENT SCADA ALASKA POWER AUTHORITY FIG.5 ANCHORAGE-FAIR BANKS INTER TIE:APA/CEA/GVEA/DIVCOM COMMUNICATIONS eer a7e4|W384 -SYSTEMS SCHEDULE ALASKA INTERTIE DATA AND CONTROL Di sili L&GSI/SCI DATA LINK MEETING January 8,1985 Attendees Anchorage Municipal Light &Power (AML&P)Bob Day Golden Valley Electric Association (GVEA)Barry Lyons Systems Control Ine.(SCI)-Robert Boardman -Chris Schofield -Lee Patmore (Dove Computing) Landis &Gyr Systems Ine.(L&GSI)-Bill Bounds -John Russel -John Prewit Chuck Broman Alaska Power Authority (APA)-Steve Muchlinski The meeting was opened by handing out the agenda,introducing the attendees,and discussing the purpose of the meeting. AML&P described their SCADA system supplied by SCI.The system is due to ship in mid-February,but some slippage may occur.SCI would like to use AML&P's system for data link software development since it's the only system on the floor that has the PDP 11/44 computer.SCI reported that some software development could be performed on their VAX based development system.AML&P reported that some slip in the delivery schedule could be tolerated providing operational problems would be taken into consideration. GVEA described their EMS system supplied by L&GSI.The system is presently being installed and will complete site acceptance tests before the end of January. L&GSI will be able to develop Data Link software on their in-house VAX based system. It was agreed by all that the testing of the data link both at the factory and on site needs to be addressed early in its development. The discussions then continued with a detailed review of the December 31,1984 version of the Alaska Intertie Data and Control Requirements document.The following highlights the discussions and agreements made during the review. 1.Exclude the initial link between AML&P and CEA shown in Figure la from the discussions.SCI mentioned that they could not be responsible for the non-standard link between AML&P and CEA. 11. 12. 13. 14. 15. 16. Software would be implemented to support the scheme represented by Figure1b.This shows a complete network with three or more nodes each capable of communicating with each other. Although event triggering was agreed to be within the scope of the functional requirements,GVEA and AML&P will have to define a list of triggering events. Add a fourth bullet to the list in Section 2.2.1,"on a remote node request". The addition of page numbers was requested to ease document reference. Add quality flags to telemetry data to indicate quality such as,manually entered,a point in scan,out of scan,ete.GVEA and AML&P to develop a common set of quality flags. Both SCI and L&GSI agreed to employ DECnet's task to task communications scheme unless some alternative is found to better suit the overall requirements. The list formats were reviewed in detail and all agreed that their format required revision;this included revision of the message header. One list will always equal one message wherever possible.Also,during the design phase,a maximum message size will be defined. Add the time of message origination to the header to within a resolution of one second. Discussed the format to be used for floating point values.The DEC standard is to be assumed unless GVEA or AML&P provide instructions otherwise. AML&P and GVEA to define a common set of device states for binary and multiple state devices for all device types. Appendix A,List 8,agreed that one byte will be used per device rather than one bit. GVEA and AML&P agreed to reconsider the contents of List 3 which currently shows the equipment status in text form. Data link reinitialization will include a sequence whereby the new user always takes responsibility for requesting any data required to bring their data base up to date.This will be accomplished through outbound remote node request messages. Drop the requirement for transmitting lists using a report by exception scheme.Assumed that adequate response could be achieved by scheduling different messages at different frequencies and that the bandwidth of the data link would be more than adequate to handle the current and future loading anticipated. As we were running out of time,we agreed to skip Item 2 on the agenda which was to address the technical considerations related to the use of DECnet.Further review of this item was postponed until SCI and L&GSI can meet again to address technical issues. Item 3 on the agenda,Milestones and Schedule,were addressed by the following: 1.Agreed to hold a technical meeting between SCI and L&GSI on January 15th. 2.L&GSI and SCI agreed to jointly develop a functional requirements specification for the data link and to submit a draft for review by AML&P, GVEA,APA by the January 22,1985.L&GSI to copy and distribute. 3.L&GSI and SCI agreed to each submit individual lists of milestones with completion dates wherever possible by the January 29,1985. ForMyVSpeti V DISPATCH SCHEDULING SUBCOMMITTEE MEETING bsiaiv MEETING HELD AT 1:30 P.M. . AML&P Conference Room -Anchorage,Alaska Jaf 6G The following personnel were in attendance: Marvin Riddle GVEA Ray Duncan CEA Hank Nikkels AML&P Myles Yerkes APA Khan APA Dan Rice Gilbert Commonwealth The Subcommittee reviewed the responses from Gilbert Commonwealth on the Anchorage Fairbanks Intertie Operator's handbook.Gilbert Commonwealth would like responses in one week so they can finalize the manual. The Subcommittee reviewed and recommended that the NERC Guide #10, Operating Reserve Capacity,be adopted by the Operating Committee. The control performance criteria be adopted by the Operating Committee with the understanding these be reviewed after the first control performance. AML&P proposed that they will install a Dunstan controller at Plant #2;this they feel will maintain schedules for the intertie until their SCADA/AGC is in full operation.Then the Dunstan controller will revert to a standby controller. ALASKA POWER AUTHORITY 334 WEST Sth AVENUE -ANCHORAGE,ALASKA 99501 Phone:(907)277-7644 (907)276-0001 February 4,1985 |ve| Mr.Bob Orr,Chairman My ES Anchorage-Fairbanks Intertie Operating Committee ao UyC/O Golden Valley Electric Association pistsP.O.Box 1249 Fairbanks,Alaska 99707 SUBJECT: Dear Bob: APA Representatives for Operating Committees With the recent departure of Mr.Yerkes,I wish to advise you of the Power Authority personnel who will be assigned to the various Operating Committees.They are as follows: AFZAL _H.KHAN Operating Committee Relay/Protection Subcommittee Scada/Metering/Communication Subcommittee Reliability/Criteria Subcommittee SVS Evaluation Subcommittee LARRY WOLF Dispatcher/Training Subcommittee HOWARD THACKE Reserves/Loadshed Subcommittee Mr.Howard Thacke has recently accepted the Power Authority position of Director of Production and Planning,and will begin his employmentonFebruary25,1985. Please address all related correspondence accordingly.If you have any questions,give me a call. Sincerely,LL VKIOLDavidR.Eberle Project Manager DE/ka ec:A.Khan,APA -__ L.Wolf,APA H.Thacke,APAMesMaSSTACAMLaaSi oy "a ' 4SCSeeSORTTOPTESDECRTOPTNREDEDSPOORESTSTORYSCHOLYTNEWOULENSOnTONECTOOEEFVUES| ALASKA POWER AUTHORITY 334 WEST Sth AVENUE -ANCHORAGE,ALASKA 99501 Phone:(907)277-7641 (907)276-0001 February 4,1985 Recd /'¢/5bt[6S , / Mr.Bob Orr,Chairman Pon Sify Anchorage-Fairbanks Intertie Operating Committee C/0 Golden Valley Electric Assoc. P.0.Box 1249 ytSFairbanks,AK.99707 y SUBJECT:Presentation on Static Var Systems DI sTAIb 70H Dear Bob: This letter will confirm our discussion relative to the concerns which have recently arisen regarding the start-up characteristics of the Anchorage- Fairbanks Intertie Static Var Systems (SVS). In an attempt to clarify any misunderstandings regarding the operation of the SVS systems and to clearly identify any undesirable characteristics or impacts to utility systems,I have requested General Electric andGilbert/Commonwealth to make a presentation on SVS during the next Operating Committee meeting scheduled for February 14,1985. Specifically I have asked that they be prepared to discuss the following: a.Start-up and shut down procedures for the SVS. b.Impact on utility systems during SVS start-up and shut-down.(i.e.voltage fluctuationns,transient harmonics,etc.) c.Automatic protection and alarm devices included with SVS. d.Range and type of possible adjustments to the SVS as presently designed which may mitigate any undesirable impacts to utility systems. e.Potential modifications to the SVS to mitigate any undesirable start-up characteristics. f.Respond to questions that may be raised concerning operating restrictions identified by the GE studies. CO.MKKEES DAL See ED ar YO ee eteOt sehr dese ieneet Be Bs ahs Sekai eaeaea Re oveSa Aree eee i Pla Li nme le 2 in na Te ae cr sale 'weAieleSAee Page 2 Mr.Bob Orr February 4,1985 As you suggested,I have contacted Mr.Mike Massin,secretary of the Operating Committee ,and had the SVS presentation added to the agenda for the February 14,1985 meeting.The presentation will be made during the afternoon session. By copy of this letter,I am advising Operating Committee members of the SVS presentation and ask that they notify appropriate individuals within their organization. If you have any questions,please give me a call. Sincerely, ZIRE David R.Eberle Project Manager DE/ka cc:John Marshall,CEA Jim Hall,MEA Mike Massin,ML&P Sam Mathews,HEA Stan Sieczkowski,Ak.Power Admin. Marvin Riddle,GVEA Larry Colp,FMUS A.Khan,APA Mike Yerkes,FYPS C.R.Parrish,M-K Lytle Miller,G/C Dan Rice,G/C Phillip Sherman,GE Pag ents we ,.ean hal wasn aban,hteeinsa OTe,Sea a oo 2.9)\=CCHBINEO ROMMETERING -ae prey DISPATCH SCHEDULING COMMITTEE”pistabecerMinutes February 5,1985 Anchorage,Ak. ATTENUANLE =Linda Stewart,CEA ".64-0751 "Ray Duncan,CEA , Ysors Teedett |TEARevertxSey;aA Rie'Harold Smith,HEA (PPD):i'Larry Wajls,CEA5KarenParsons,CEA (PCC)564-0958 -7EPPagetioepRARENAPPETOEERIEEPOJ gbm Hall,MEA 754-3231 <Afzai H.Khan,APA 276-0001.'Stephen Huch]inski,G/C.(206)882-3071 o©Marvin Riddle,GVEA 2 G52-3951 The combined SCADA/metering Dispatch Scheduling meeting was called to orderby&.Day,acting chairman.CEA asked the question if 5CIi had responded totheirproposaltoemulatetheDecnetandtietoAMLEP.Bob Day,AHLEP,statedtheirvendorhadnotrespondedtothetEAproposalyet.-ro3,Marvin Riddle trousht up the accountina probleas associated with the etartenofthe,Helines.He ré¢onmerde de star?lp the fa ferfresPerCencayeoFjossesuntilsuchatimethattheoperatingcommitteedeterminessufficientinformationandequipmentisavailabletorunonlineloadFlas for loss calculation. Wag ihe Gocument entities "Fonctisnal specification tor the intertie”from Ls 5 dated Janyary 22,1985 was reviewed with the following comments: tg) an:CEA exceptions to functional specifications i. 1)They still propose to be a send/receive node,only not a routing node. 2)Why Uecnet Phase (W is specified.is software fully available?No "-gocumentarion is presentiy available for Phase tv...1s Phase iW BEATS :compatibie to Fnase Wit a cn hb)4.3{j)in response to a remote request for data,CEAnot+equipped @cand 'gon?c Pprovoeze to syreert this :ity a -..8 5153 Fiease ciarify data packet nsager,why cay.month.vear,AresuurceTaciiityandtargetfaciiityrequired?uj}6h |oevent triagers -LtA mas an oojection to a request received Froaa@femotesiterortransmissionofaspecificmessageorlistofmessages,. ae 'ine. sah% as! < + pea am. DEE POF Ane patom* is©. a bateMe aoe driaaereat ae ott iA 5ik cht Ta ” Rade Cee een en. Ae fine ' 3t peci fications:ty t usin fosett'the Decenber=Fam ing with developmen lect nd reconssends updating nk toa refAISGocumes $a tendent ine Ly oneat t line operator ts proceed cr auldal e. omnlttea. trot requ nd South.ti i xPaz cs ng¢ ystem Oispatch Supe rth.No rat = & EA Sf ° to ; Ce Bes a ; "eat 2 ag AhnBHay Fai aNY % yoy ME gh Nae ata!* *