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Home My WebLink AboutBradley Lake PMC Meeting Teleconference Thursday 06-21-2001STATE OF ALASKA / -enom DEPARTMENT OF COMMUNITY AND S83 WEST FOURTHAVE, SUITE 220 R E A I A F FA I RS ANCHORAGE, ALASKA 99501-2341 GION. PHONE: (907) 269-4500 DIRECTOR'S FAX: (907) 269-4645 DIVISION OF ENERGY ENGINEERING PAX: (007) 208-4685 x, %,9 printed on recycled paper b y C.D AAABARBAR ARBAB ARBAB ABA RB RBBB ARR ARR RRR KI KIRK IRIRCR ORC 110100000000 OOOO OOOO OOK 2S eK OE DE DE OK OME ME OK OK HK ODE ODE TRANSACTION REPORT io SATAN JUN-14-01 THU 10:37 AM SEND (M) DATE START — RECEIVER TX TIME PAGES TYPE NOTE M# DP JUN-14 10:36 AN 92798170 36" 2 SEND (M) OK 002 TOTAL 36S PAGES: 2 SOOO CO OOOO OOOO OOOO OOO OOOO OOOO OO OOO OOOO OOOO OOO OOOO OOOO OOO OAC OKO OOOO OOOO OOK K ALASKA INDUSTRIAL DEVELOPMENT = > ¢ AND EXPORT AUTHORITY {= ALASKA @E =ENERGY AUTHORITY 813 WEST NORTHERN LIGHTS BLVD. ¢ ANCHORAGE, ALASKA 99503 © 907/269-3000 * FAX 907 / 269-3044 TOLL FREE (ALASKA ONLY) 888 / 300-8534 June 14, 2001 FAXED: 06/14/01 2 PAGES Anchorage Daily News 4001 Northway Drive Anchorage, Alaska 99508 ATTENTION: Ms. Eva Alexie Legal Classified Subject: Public Notice Account # ALASO709 Enclosed is an advertisement for the Alaska Energy Authority, which is to be published under “PUBLIC NOTICE” in the Legal Classified section in column format. This notice needs to be published for one day: Friday, June 15, 2001. x x X X X x X X x x XK X x x “ail ALASKA INDUSTRIAL DEVELOPMENT * AND EXPORT AUTHORITY {= ALASKA im =ENERGY AUTHORITY 813 WEST NORTHERN LIGHTS BLVD. ®© ANCHORAGE, ALASKA 99503 © 907/269-3000 ¢ FAX 907 / 269-3044 TOLL FREE (ALASKA ONLY) 888 / 300-8534 June 14, 2001 FAXED: 06/14/01 2 PAGES Anchorage Daily News 1001 Northway Drive Anchorage, Alaska 99508 ATTENTION: Ms. Eva Alexie Legal Classified Subject: Public Notice Account # ALASO709 Enclosed is an advertisement for the Alaska Energy Authority, which is to be published under “PUBLIC NOTICE” in the Legal Classified section in column format. This notice needs to be published for one day: Friday, June 15, 2001. After the publication date, please provide an Affidavit of Publication. If you have any questions, please do not hesitate to call me. Thank you, Shauna Dean Admin. Assistant Attachment STATE Ob ALESHA) -rrteme exemen DEPARTMENT OF COMMUNITY AND 394 WEST FOURTH AVE, SUITE 220 REGIONAL AFFAIRS ANCHORAGE, ALASKA 99501-2341 PHONE: (907) 269-4500 DIRECTOR'S FAX: (907) 269-4645 DIVISION OF ENERGY ENGINEERING FAX: (907) 269-4685 & printed on recycled paper b y G.D AN AIR AN IRAN IN AN IRIN IRAN IN INN IRIN INN INTIS NINN INNIS A RADAR AA DA ADR ADD ADA A ADARAADRADAR ADR ARAARA RR ARR AR ARAB AAR ARARARARARARARARA X X X X X x x x X X x x Xx X x x X x X x BROADCAST DATE START JUN-12 08:38 AM 95626994 RECEIVER 08:39 AM 919072353323 09:12 AM 919077459368 08:41 AM 92635204 08:42 AM 919074585951 08:43 AM 919072244085 08:44 AM 915032260079 P, 01 TRANSACTION REPORT SMT TTT TTT JUN-12-01 TUE 09:12 AM TX TIME PAGES TYPE NOTE 33” 2 SEND (M) OK 187 32" 2 SEND ( M) OK 187 ax XX" 0 SEND (M) BUSY 187 30” 2 SEND (M) OK 187 32”. 2 SEND (M) OK 187 33” 2 SEND (M) OK 187 30” 2 SEND (M) OK 187 TOTAL 3M 10S PAGES: 12 10000000100010000 1010100 1000000000000 OOK N OOOO KONO CO CCN K NCCI NCCC N CCK CCC COCCI N OOK PLEASE DELIVER TO THE FOLLOWING: Eugene Bjornstad Norm Story Wayne Carmony Michael Scott Steve Haagenson Dave Calvert Ron Saxton Chugach Electric Association Homer Electric Association Matanuska Electric Association Anchorage Municipal Light & Power Golden Valley Electric Association City of Seward Ater Wynne LLP (907) 562-6994 (907) 235-3323 (907) 745-9368 (907) 263-5204 (907) 458-5951 (907) 224-4085 (503) 226-0079 M# DP X X X X X X X x X x X X x X X X X X x X STATE OF ALASKA, 7 merones semen DEPARTMENT OF COMMUNITY AND 333 WEST FOURTH AVE., SUITE 220 ANCHORAGE, ALASKA 99501-2341 REGIONAL AFFAIRS ANCHON a een DIRECTOR'S FAX: (907) 269-4645 DIVISION OF ENERGY ENGINEERING FAX: (907) 269-4685 & printed on recycled paper b y C.D. SEND (iM) DATE START — RECEIVER JUN-12 09:09 AN 96899368 De DK DK KE KE OK KE OK OE KE OK OME OK P, 01 x TRANSACTION REPORT x a ee a — JUN-12-01 TUE 09:09 AM = x x X x TX TIME PAGES TYPE NOTE M# DP x hv x 33” 2 ‘SEND (M) OK 188 =x Ch er x X TOTAL 33S PAGES: 2 x X SOOO COO OOOOOOOOOOO OOOO OOOO OOOO OOOO OOOO OOOO OOOO OO OOOO OOOO OOOO OOOO OOOO OOOO OKA OOOO KU KX PLEASE DELIVER TO THE FOLLOWING: Eugene Bjornstad Norm Story Wayne Carmony Michael Scott Steve Haagenson Dave Calvert Ron Saxton Chugach Electric Association Homer Electric Association Matanuska Electric Association Anchorage Municipal Light & Power Golden Valley Electric Association City of Seward Ater Wynne LLP (907) 562-6994 (907) 235-3323 (907) 745-9368 (907) 263-5204 (907) 458-5951 (907) 224-4085 (503) 226-0079 Notification of Bradley Lake Project Management Committee Meeting Teleconference meeting is scheduled to be held on Thursday, June 21, 2001, at 10:00 a.m. Packets for this teleconference are scheduled to be sent out this week and will include directions for connecting to the conference call. Please call Shauna at (907) 269-3028 with questions. h:\all\sdean\bradley\mtg notification fax cover.doc PLEASE DELIVER TO THE FOLLOWING: Eugene Bjornstad Norm Story Wayne Carmony Michael Scott Steve Haagenson Dave Calvert Ron Saxton Chugach Electric Association Homer Electric Association Matanuska Electric Association Anchorage Municipal Light & Power Golden Valley Electric Association City of Seward Ater Wynne LLP (907) 562-6994 (907) 235-3323 (907) 745-9368 (907) 263-5204 (907) 458-5951 (907) 224-4085 (503) 226-0079 TELECONFERENCE INSTRUCTIONS Thursday June 21, 2001 — 10:00 a.m. To join the teleconference, please do the following: Dial 1-800-315-6338 Enter 0621# < ALASKA INDUSTRIAL DEVELOPMENT * AND EXPORT AUTHORITY /= ALASKA @E™ = ENERGY AUTHORITY 813 WEST NORTHERN LIGHTS BLVD. *© ANCHORAGE, ALASKA 99503 © 907/269-3000 © FAX 907/269-3044 TOLL FREE (ALASKA ONLY) 888 / 300-8534 ALASKA ENERGY AUTHORITY/ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY Public Notice Bradley Lake Project Management Committee Notice is hereby given that the Bradley Lake Project Management Committee will hold a regular meeting on Thursday, June 21, 2001, at 10:00 a.m. This meeting will be held via teleconference at the following location: Alaska Industrial Development and Export Authority, 813 W. Northern Lights Boulevard, Anchorage, Alaska. For additional information contact Eugene Bjornstad, Chairman. The State of Alaska (AIDEA), complies with Title Il of the Americans with Disabilities Act of 1990. Disabled persons requiring special modifications to participate should contact AIDEA staff at (907) 269-3000 to make special arrangements. /s/ Alaska Energy Authority Project Management Committee Publish: Friday, June 15, 2001 ALASKA INDUSTRIAL DEVELOPMENT _ » ¢ AND EXPORT AUTHORITY f= ALASKA im ~=ENERGY AUTHORITY 813 WEST NORTHERN LIGHTS BLVD. *® ANCHORAGE, ALASKA 99503 ¢® 907/269-3000 ¢ FAX 907 / 269-3044 TOLL FREE (ALASKA ONLY) 888 / 300-8534 BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE MEETING VIA TELECONFERENCE AGENDA Thursday, June 21, 2001 — 10:00 a.m. (Via electronic media at AIDEA/AEA — 813 W. Northern Lights Boulevard) 1. CALL TO ORDERi~ Bjornstad 2; ROLL CALL (for Committee members) a 3. PUBLIC ROLL CALL (for all others present) ~~ 4. PUBLIC COMMENT »~ 5. | AGENDACOMMENTS -~ 6. APPROVAL OF MEETING MINUTES ~~ March 20, 2001 yet @ paved May 11, 2001 Pi ts NEW BUSINESS A. Status Report — Remedial Action Scheme Ato Hickey fo n ; ; B: Status Report —- Governor ~—— : Hicke nets, inate . 8. COMMITTEE COMMENTS aa Prema A. Next Meeting Date Bjornstad 9. ADJOURNMENT Sart — getting papermok’ Y Papen. Agenda Item No. CITY OF SEWARD MATANUSKA ELEC ASSOC CHUGACH ELEC ASSOC HOMER ELEC ASSOC GOLDEN VAL ELEC ASSOC MUNI LIGHT & POWER ALASKA ENERGY AUTHORITY A=4+ OVER 51% B = AEA CONCUR With A BRADLEY PMC VOTING DATE: ves No ABS ves ans YES NO ABS peace ieee ee Bie | Ta eet a 30% ee saa ee ee RPOa Tera ir mae IS 26% [ ci | Pr C = UNANIMOUS D = MAJORITY VOTING METHOD A: Requiring four yeas with 51% of utilities, with no AEA vote: 1) Procedures for scheduling, production and dispatch of project power. 2) Establishment of procedures for use of each purchaser's water allocation (AEA assent required for license requirements). 3) Selection among alternative methods that do not involve AEA for funding required project work. VOTING METHOD B: Requiring 4 yeas with 51% of utilities and AEA concurrence: 1) Arranging operation and maintenance of project. 2) Adoption of budget of annual project costs. VOTE(93Q3/BC5272) 3) Establishment of FY estimated annual payment obligation and schedule of each purchaser. 4) Determination of annual project costs after each FY. 5) Evaluation of necessity for and scheduling of required project work. 6) Determination of appropriate amount of insurance. 7) Adoption of additional minimum funding amounts for renewal and contingency reserve fund above that required by bond resolution. 8) Selection among alternate methods that involve AEA for funding required project work. 9) Adoption or amendment of procedural committee rules (except dispute resolution). 10) Adoption of project maintenance schedules. 11) Determination of rules, procedures and accounts necessary to manage project when no bonds outstanding. 12) Evaluation and approval of optional project work and compensation for such work. 13) Application of insurance claims proceeds not governed by bond resolution. 14) Approval of procedures and any individual utility agreements relating to electric power reserves for project. 15) Approval of consultants. VOTING METHOD C: Unanimous vote by all (including AEA) VOTING METHOD D: Majority vote (including AEA) Election of Officers y Agenda Item No. CITY OF SEWARD MATANUSKA ELEC ASSOC CHUGACH ELEC ASSOC HOMER ELEC ASSOC GOLDEN VAL ELEC ASSOC MUNI LIGHT & POWER ALASKA ENERGY AUTHORITY A=4+ OVER 51% B = AEA CONCUR With A BRADLEY PMC VOTING wh Lol Col/ DATE: 6/2(/ 0! Oe el pe ls we wm 4223) Eee Fol os iat] Ey EEE | 1% (TT Es Fa meee ERE Se $e) Ee) Sed Ee Ee be C = UNANIMOUS D = MAJORITY VOTING METHOD A: Requiring four yeas with 51% of utilities, with no AEA vote: 1) Procedures for scheduling, production and dispatch of project power. 2) Establishment of procedures for use of each purchaser's water allocation (AEA assent required for license requirements). 3) Selection among alternative methods that do not involve AEA for funding required project work. VOTING METHOD B: Requiring 4 yeas with 51% of utilities and AEA concurrence: 1) Arranging operation and maintenance of project. 2) Adoption of budget of annual project costs. VOTE(93Q3/BC5272) 3) Establishment of FY estimated annual payment obligation and schedule of each purchaser. 4) Determination of annual project costs after each FY. 5) Evaluation of necessity for and scheduling of required project work. 6) Determination of appropriate amount of insurance. 7) Adoption of additional minimum funding amounts for renewal and contingency reserve fund above that required by bond resolution. 8) Selection among alternate methods that involve AEA for funding required project work. 9) Adoption or amendment of procedural committee rules (except dispute resolution). 10) Adoption of project maintenance schedules. 11) Determination of rules, procedures and accounts necessary to manage project when no bonds outstanding. 12) Evaluation and approval of optional project work and compensation for such work. 13) Application of insurance claims proceeds not governed by bond resolution. 14) Approval of procedures and any individual utility agreements relating to electric power reserves for project. 15) Approval of consultants. VOTING METHOD C: Unanimous vote by all (including AEA) VOTING METHOD D: Majority vote (including AEA) Election of Officers Bradley Lake PROJECT MANAGEMENT COMMITTEE MEETING 6 -2/-9/ (Date) ALYEA -Tebnoprenn, (Location) PLEASE SIGN IN No. NAME mT REPRESENTING 1 Raps. | AEA 2 | Gere Secs Pe Ee = 7 3 Beqw 1! rer, ji CHUGAL ey 4 | Lee TH eEZT CyHu64cy ||| clea Cou CHU ACME 6 7 au 9 10 Ul | 12 | 13 14 15 | 16 | ir 18 | |_19 | |_20 | | a | 22 | 92Q2\IT9884 Vor idk thd svelvda a Xe [voree Naw 7 at cele tao — Sarebo. 7 see is if it a = sipaitionsl Cast . eed 4 ae Driee > Cw. Ms Lf ed ee ages = be taptlfen Naw = lenp oh typhi —B ele bai fsa. « S fib 2 pu syenl eve. ae -4M ars ee 1D rm pedle-]ppreler - Norm '*LSA hb dry rw Plow Deb 2-6 om BU LH brad rer Nt Bile dhe igh cde oo cB ‘de ae a ce Aincte — Mite Sa deh ve ee Se tt Sti be = Avrora - eth tixernads bre to toll ctaboy. prADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCIA. .W44, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM will be required to expire prior to tripping the first unit. The second unit will be tripped 5 seconds after the first unit, if the oscillations have not decreased sufficiently (peak to peak oscillations of less than 30 MW). 7 Preliminary Schedule and Budgetary Cost Estimate The design phase of the RAS project, assuming a notice to proceed and an approved design by 5/1/01, could be completed by 5/30/01. Based on plant personnel availability, it is anticipated that the installation could then commence on 6/1/01 and be completed by 6/8/01. Testing could then commence and be completed by 6/15/01, assuming plant scheduling could be arranged. The budgetary estimate for the Bradley RAS is $32,200." ' This includes the RAS hardware ($5000), programming, and markups of plant drawings ($15,000). Installation cost is estimated to be $ 3,000 (3 man-days, ten hours, $100/hour loaded). Estimated testing cost (personnel only, no power production costs included) is $ 8,000 (three test engineers, plus one plant personnel, two days, ten hours per day, $100/hour loaded). Estimated direct expenses for testing and installation is $1,200 (2 RT aircraft for testing/installation @ $200/RT and 8 days subsistence @ $50/day — HEA provided housing). ELECTRIC POWER SYSTEMS PAGE 8 MARCH 2001 prADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCIAv wi, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM e Unit 2 Deflector in Stream e Unit 1 Oscillation Detected e Unit 2 Oscillation Detected e Unit 1 reduce needle opening e Unit 2 reduce needle opening e Unit 1 Trip e Unit 2 Trip Responsibilities: EPS will design and implement the Bradley RAS, with assistance from Chugach for specification of the “deflectors in stream” calculation. Plant personnel will perform the installation of the system at the plant, and the interface of the system to local and SCADA annunciation. 6 Potential Negative Effects of the RAS The Bradley RAS is designed to operate independently of dispatcher intervention, and thus has predictable results. The potential “negative” effects of implementing the system as described are attributable only to the scenarios where control would be exerted. 6.1 Reduce Bradley Unit Needle positions If the RAS detects the deflector is in the stream, it will attempt to reduce the needle openings to the point that the deflectors are no longer in the stream. For the envisioned application, no significant real power output reduction should occur. The only effect would be to reduce the needle openings so that the deflectors are no longer in the stream. The control system will have verification in the control loop to limit any real power reduction due to this mode of remedial action. 6.2 Trip Bradley Lake units If the oscillations are severe, and the reduction of the Bradley needle positions fails to arrest the oscillations, then the RAS will sequentially trip the Bradley units. One unit will be tripped first, and time allowed to determine if the oscillations are diminished or arrested. If the oscillations do not cease, the second Bradley unit will be tripped so as to minimize damage to the units. If one or both units trip, and, depending on system configuration and spinning reserve, loadshedding may occur throughout, or in a single area of the interconnected system. The tripping logic will only be armed after (1) the “deflector in stream” alarm condition is detected, and (2) oscillations have been detected, either in the real power output or in the deflector “change in direction” calculation. After arming the trip, a timer (10-15 seconds) ELECTRIC POWER SYSTEMS PAGE7 MARCH 2001 \ ~. ADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCI....~.\, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM e Determination of oscillations by looking at the deflector position transducers, and noting three sequential changes in direction of the deflector motion over a four second period. The detection of an oscillation by the local control system will be annunciated to dispatch via the RTU. e Measurement of deflector and needle position, and the mathematical determination of if the deflector is in the stream. The detection of the deflector in the stream will be annunciated to dispatch. e Reduction in the needle openings if the deflectors are determined to be in the stream. The controlled reduction of needle openings will be annunciated to dispatch. e Tripping of the units if “large” oscillations occur for,greater than 10-15 seconds. The implementation of the RAS as described above keeps the dispatcher informed of events and statuses at the plant, but does not require the dispatcher to intervene in order for the system to perform control. 5 Proposed Remedial Action System Implementation The Bradley RAS team proposes to implement the RAS design criteria as follows: 5.1 Local Processing The local control will consist of a GE 90-30 PLC system with the following inputs and outputs: Inputs e Bradley Unit 1 MW e Bradley Unit 2 MW e Deflector position e Needle position e Override control system (Chugach SCADA) e Vibration Detected Outputs e Unit 1 Power > 30 MW e Unit 2 Power > 30 MW e Unit 1 Deflector in Stream ELECTRIC POWER SYSTEMS PAGE6 MARCH 2001 \ ADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCI, A, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM When the RAS determines that the deflectors have entered the stream, the system dispatcher will be notified via the Chugach SCADA system, that he is operating the plant in a mode where oscillations are possible. 3.3 Begin aggressive control to remove the deflectors from the stream at Bradley When the deflectors are determined to be in the stream at Bradley, and the dispatcher has been notified, the local RAS system will then begin to aggressively close the needles, effectively removing the deflectors from the stream. If the units are in steady state operation, the system will see no appreciable reduction in real electrical power from the Bradley Plant. 3.4 Provide aggressive setpoint control when oscillations are detected When oscillations are detected at Bradley, aggressive control should be implemented at Bradley in an attempt to dampen the oscillations. The local RAS will annunciate to SCADA that local control action is being taken, and the needle openings will be aggressively reduced. This will result in a reduction of mechanical input power to the turbine, thus reducing it’s ability to constructively sustain or exaggerate the oscillations. The aggressive reduction in the mechanical input power of the machines could result in some loadshedding. 3.5 Trip Bradley units if oscillations continue In the case where the local RAS control fails to arrest the oscillation of the Bradley units after 10-15 seconds, and the magnitude of the oscillation are determined to be sufficient to cause possible damage to the units (>+30 MW), the Bradley units should be tripped so as to avoid additional, and possibly increasing, forces on the shafts. The time to trip and magnitude of the oscillations are not analytically derived, but based on the utilities current experience with prior Bradley oscillations. The tripping of the Bradley units will likely result in loadshed throughout the interconnected system. 4 Proposed Remedial Action System Conceptual Design Bradley oscillations have been observed to have a period in the 600 mS range. This period of oscillation requires the processing of plant data onsite in order to avoid aliased data. A local control/processing system will be required onsite to perform the following functions: e Measurement of machine real power output, and the detection of oscillations (in part) by observation of the change of direction of power from the units. This will detect both plant-system oscillations, as well as unit-unit oscillations. The detection of an oscillation by the local control system will be annunciated to dispatch via the RTU. ELECTRIC POWER SYSTEMS PAGES MARCH 2001 vie pRADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCIA 1uN, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM should not rely on the dispatchers for intervention during or just prior to, an oscillatory event. MM terete me eet ete i) The RAS at Bradley will be designed to perform annunciation and control functions so as to alarm dispatch personnel when the plant is operating in a potentially critical operating range. Should a deflector be in the stream, the RAS will exert control in an attempt to minimize the likelihood of an oscillation occurring. If an actual oscillation is detected, the RAS will exert control to dampen the oscillations. Specifically, the Bradley RAS will be constructed to: e Annunciate when either of the units are above a MW level that in the past has exhibited oscillatory behavior. e Annunciate when the deflectors are in the water stream at Bradley. e Ifthe deflectors are determined to be in the stream, begin aggressive control of the needles to reduce the water stream such that the deflectors effectively come out of the stream. e If oscillations are detected at Bradley, provide aggressive setpoint control to reduce the needle openings at Bradley unit, in order to dampen or minimize the oscillations at Bradley. e If the oscillations continue, trip the Bradley Lake units offline to minimize their exposure to the potentially damaging oscillations. The Bradley RAS can be disabled from dispatch by a “poke point” on the Bradley Lake plant display. This will allow the system dispatcher to disable the RAS system, should it misoperate, or if unforeseen system conditions require it’s temporary deactivation. 3.1 Annunciate when either of the Bradley units are above a given MW output The Bradley oscillations are generally observed when the machines are above 30 MW, while in six needle operation. The local Bradley RAS system will annunciate to dispatch when either of the units are operating above 30 MW. No specific dispatcher action is required, other than to note that the units are operating in a region where oscillations are possible. 3.2 Annunciate when the deflectors are in the stream at Bradley Both the deflector and needle positions have transducers installed. Given the position indications from the deflector and needle transducers, it can be mathematically determined when the deflectors enter the water stream. ELECTRIC POWER SYSTEMS PAGE 4 MARCH 2001 \ ADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCIni 1, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM 1. Background and Scope Since the commissioning of the Bradley Lake units, large-scale oscillations have been observed. While observed and recorded on the power system, these oscillations were not reproducible in or anticipated by any of the system studies performed by the Bradley design consultants. In 1997-98, in a cooperative effort between the Bradley owners and Electric Power Systems, Inc. (“EPS”), a computer model was developed whereby the oscillations could be produced and characterized in simulation. Subsequent to the system studies with the “new” model, the Bradley plant was instrumented and testing done on the units to further understand the oscillations and the causes. Oscillations observed previously and predicted in simulation were successfully induced in the online Bradley testing. One of the long-term solutions to the Bradley oscillations involves improvements to the Bradley governor system. The task of defining and implementing a new governor algorithm is currently under study by the utilities. In the interim, a remedial action scheme (“RAS”) is required to (1) alert the system dispatchers when the plant is operating in an area where it may be susceptible to oscillations, (2) initiate plant control in order to dampen or minimize the length and magnitude of the oscillations, and (3) should the oscillations continue, trip the Bradley units in order to minimize their exposure to potentially damaging forces to the machines. Chugach, under the direction of the Bradley Lake Project Management Committee (“BPMC”) and the Bradley Lake Operations and Dispatch Subcommittee (“O&D”), has assembled a team to undertake the definition and implementation of the RAS. 2 Description of Problem The units at Bradley Lake are subject to potentially severe oscillations for the following conditions: 1. The oscillations are observed when the deflectors are in the water stream. 2. Operation of any unit over approximately 30 MW output. The 30 MW criteria is based on observed behavior of the plant, and not on any analytical investigation. 3. The oscillations are observed to start primarily when there is an overfrequency event on the system. This causes the deflectors to cut into the stream, thus satisfying the requirement (1) above. The risk of damage to the units is not defined at this time, but it is anticipated that there is some potential for damage, give the large oscillations that have been observed. It was also noted in the RAS project scoping meetings that the RAS system needs to annunciate to dispatch personnel the status of the plant with regard to remedial action, but ELECTRIC POWER SYSTEMS PAGE3 MARCH 2001 ~. ADLEY LAKE PMC/CHUGACH ELECTRIC ASSOCI,...0.1, INC. BRADLEY LAKE REMEDIAL ACTION SYSTEM TABLE OF CONTENTS 1 Background and SCONe ssssscsccacsccstincssessdsescsssesccscssctsasesineysasesepiansdbvessestutessachstovevgeeaesessussvensnd 3 2 Description of Problem... 3 Discussion of Remedial Action System..........scssssssserssssessseeseseseeseeeseseseeseesseseenenseseeeeneese 4 3.1 Annunciate when either of the Bradley units are above a given MW output ..............:ecceceeeeeeeeee 4 3.2. Annunciate when the deflectors are in the stream at Bradley 3.3 Begin aggressive control to remove the deflectors from the stream at Bradley .............scscsseee 5 3.4 Provide aggressive setpoint control when oscillations are detected .............c:cccccsessseeeesereeeseees 5 3:5. Trip.Bradley units if Oscillations COMINUG wisiscevacsaccassscgtasteeacst etascsrsienstersassieecadenteeasattavenevseesg 5 4 Proposed Remedial Action System Conceptual DeSiQN...........ssssssseseseesssesessteseseenenseers 5 5 Proposed Remedial Action System Implementation ..........ssssssssscsssesssessesessssssseseensearere 6 5.1 Local Processing...........cssssssscssssccesssccscsscrseseccsnscscesssseassocesesssssscossscesesescocesessscessscesseeonees 6 6 Potential Negative Effects of the RAS 6.1 Reduce Bradley Unit Needle positions ..............scssccecsssscessrcseesseseessseeeseesseeeceeesreeeceeseeseesees 7 G.2, ‘Trip Bradley! Leake: WMS sh vss sscnsssanssevaroneteerendussssposdesnssrsssene¥eessocedeusbseveeetceseevenscassebecoessbes 7 7 Preliminary Schedule and Budgetary Cost Estimate ELECTRIC POWER SYSTEMS PAGE 2 MARCH 2001 Bradley Lake O&D Bradley Lake Remedial Action Scheme March, 2001 4. PUBLIC COMMENT There were no public comments. 5. AGENDA ENT There were no agenda comments. 6. APPROVAL OF MEETING MINUTES — March 20, 2001 and May 11, 2001 Chair Bjornstad stated that the above noted meeting minutes were not going to be approved at this meeting. He noted that the minutes needed to be taken out of verbatim format and just kept to motion related items. He also noted that the Bradley Lake O&D Remedial Action Scheme report presented by Brian Hickey needed to be attached to the minutes to better clarify his verbal status report. The above sets of minutes would be brought to the next regularly scheduled meeting for approval once amended. 7. NEW BUSINESS 7A. Status Report - Remedial Action Scheme — Hickey Brian Hickey gave a brief update on the report (attached). 7B. tat — Governor — Hicke’ Brian Hickey discussed governor replacement and needle change-out. No motions were noted at this time. 8. COMMITTEE COMMENTS 8A. Next Meeting Date — Bjornstad Chair Bjornstad recommended that the next regularly scheduled meeting of the committee be held on August 28, 2001, at the Bradley Lake project site, and would include a site visit. 9. AD RNMENT There being no objection and no further business of the Committee, the meeting was recessed at 10:35 a.m. Page 2 of 2 BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE MEETING MINUTES TELECONFERENCE Via Electronic Media @ AIDEA 813 W. Northern Lights Boulevard Anchorage, Alaska Thursday, June 21, 2001 — 10:00 a.m. 1. ALL TO ORDER Chairman Eugene Bjornstad called the meeting of the Bradley Lake Hydroelectric Project Management Committee to order at 10:00 a.m. on Thursday, June 21, 2001, from the Alaska Industrial Development and Export Authority's Board Room, Anchorage, Alaska, to conduct the business of the Committee per the agenda and public notice. 2. ROLL CALL Roll was called by Shauna Dean. The following members were present: Gene Bjornstad Chugach Electric Association Wayne Carmony Matanuska Electric Association (teleconference) Norm Story Homer Electric Association (teleconference) John Grubich Golden Valley Electric Association (teleconference) Stan Sieczkowski Alaska Energy Authority (teleconference) Michael Scott Anchorage Municipal Light & Power (teleconference) Dave Calvert City of Seward (teleconference) 3. PUBLIC ROLL CALL Shauna Dean, Alaska Energy Authority Brian Hickey, Chugach Electric Association John Cooley, Chugach Electric Association Lee Thibert, Chugach Electric Association Hank Nikkels, Anchorage Municipal Light & Power (teleconference) Don Stead, Homer Electric Association (teleconference) Don Zoerb, Matanuska Electric Association (teleconference) Bob Zaharsky, Bradley Lake (teleconference) Ron Saxton, AterWynne, LLP (teleconference) Page 1 of 2