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Bradley Lake Technical Coordination Comittee 1990-1995
PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THO,DEC 07 1989 13:37 1988 WINTER PEAK.45MW KENAI IMPORT.COOPER LAKE, BERNICE #3 &SOLDOTNA UNITS SUPPLYING KENAI LOAD. 'RATOR SUMMARY: _IS NAME BSVLT #MAC TYP MW MVAR QMAX QMIN VSCHED VACTUAL REM 67 BERN 3G 13.8 1 2 10.0 4.8 13.9 -6.9 1.0300 1.0300 79 COOP1&2G4.20 2 2 16.0 -1.6 14.7 -9.2 1.0300 1.0300 691 TESORO1G24.9 1 -2 4.0 1.9 1.9 "1.9 1.0100 0.9952 998 SOLD SVS 1 2 0.0 11.8 30.0 -25.0 1.0200 1.0200 9989 9985 UNIVRSTY 115 1 3 44.7 3.6 9999.0 -9999.0 1.0500 1.0500 9994 SOLDOT1G13.8 i 2 18.0 -0.2 19.7 -5.9 1.0200 1.0200 SUBSYSTEM TOTALS 92.7 13.1 10079.2-10047.9 MVABASE=10150.9 1988 WINTER PEAK.4SMW KENAI IMPORT.COOPER LAKE, BERNICE #3 &SOLDOTNA UNITS SUPPLYING KENAI LOAD.aISOLATEKENAIUNDERYSMWIMPORTCONDITIONATT=0.S SECONDS = FILE:WP88L01X.CHN © [onl oS QO o SOLDOTNA -PMECH (MW) 50.000 hiatal °0.0 5 BERNICE =3 -PMECH (MW)= 50.000 aiinaiteetiontioe 0.0 L SOLDOTNA 115 (HZ) f 60.500 ee 58.000 +¢&|3 ee ee : :|*s 'Oo Za fl es | !|; L |"7s ¢| =!po 18 | a ball o t ° -'|_ie 1 xi| :|o _-¢]_|8 t band'4 'J e 'o Le 'J 4 '|"0 |° = |s | | ' 1 S =/d s //ss Pa / t \3 tee N S wre "8 a = 'fo]a 3 :KENAICTRESPONSETIME PTI INTERACTIVE POWER SYSTEM SIMULATOR- -PSS/E TUE,DEC 05 1989 08:57 1988 WINTER PEAK.KENAI AREA ISOLATED. COOPER @ 16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD. ERATOR SUMMARY: os NAME BSVLT #MAC TYP MW MVAR QMAX QMIN VSCHED VACTUAL REM 79 COOP1&2G4.20 2 2 16.0 -0.1 14.7 9.2 1.0300 1.0300 503 BRAD EQV13.8 1 3 72.5 -1.9 39.3 -39.3 1.0100 1.0100 691 TESORO1G24.9 1 -2 4.0 1.9 1.9 -1.9 1.0100 0.9773 998 SOLD SVS 1 2 0.0 16.4 30.0 -25.0 1.0200 1.0200 9989 SUBSYSTEM TOTALS 92.5 16.3 85.9 75.4 MVABASE=203.0 1988 WINTER PERK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD. BRADLEY W/90 SEC NEEDLE.REVISED DROOP &TIME CONSTANTS. PICK UP 3MW OF LOAD AT SOLDOTNA AT T =0.5 SECONDS. FILE:WP88TO1LX.CHN NET TURBINE HEAD (FT) 1200.0 >x 900.00 TUABINE FLOW (CFS) 1600.0 -=o +100.00 NEEOLE OPENING (PU) 1.0000 @wwrreereree-=-2 0.0 PMECH (MW) 1$0.00 ---7-7s 0.0 BRADLEY 115 (HZ) 60.500 ee 58.000 20.00016.00012.0006.00000.bite14.00018.000TUE,BRADLEYPARAMETERS6.00002.000015:19DEC051989 WIL000°hI000'010000°900002000°91000°2!0000°90000°h0'0000°al000°02¢(2H)STITT AZ 10oya 'Int-_--_---- (MW)HIaWd Qoeennnnnnne > (id}SONINSdO J1G33N eo ee ---+ ($33)MOUs 3NT8YnL ee x 6861SO3340SYUSLSWUUUdASTOUYE9€°91(ia)Ob3H SNTEYNL LIN NH3°XSONSSdM *31I4 *SONO33S S$°0 =1 LY MWS dN YIId "SINHISNOD SWIL dOOWO AQSSIASY "31033N 33S O6/M AZIOYYS "GWOT IUNSX INIAIddNS SLINA A31ObYs HLOS F MWOT &Y3d009"G3LY10S]1 bay IBN3SN "We3d YSLNIM 8867 1988 WINTER PERK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LORD. BRADLEY W/90 SEC NEEDLE.REVISED OROOP &TIME CONSTANTS. PICK UP 7MW OF LOAD AT SOLDOTNA AT T =O.5 SECONDS. FILE:WP88U01X.CHN NET TURBINE HEAD (FT) 1200.0 >x 900.00 TURBINE FLOW (CFS) 1600.0 errr +100.00 NEEDLE OPENING (PU) 1.0000 @-----------°0.0 PMECH (MW) 150.00 ---0.0 BRAOLEY 115 (HZ) 60.500 ee 58.000 *|[an | ! "x. _-_ oe ty - o UJoza©5wbCc2[oa wo Wwo> .udWWodraCc cc oC c-] t=] So o N oS S oO fo] co] Qa o o oS i=] i] = So Qo o nN 3 tuf=Co aHi o o So °o o eo oe c- So ye] S L-] o oe x oe e o t=] N 0.0 1988 WINTER PERK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD. BRADLEY W/30 SEC NEEDLE.REVISED DROOP &TIME CONSTANTS. PICK UP 3MW OF LOAD AT SOLDOTNA AT T =0.5 SECONDS. FILE:WP88T02X.CHN NET TURBINE HEAD [FT) Moree esse ees x 300.00 TURBINE FLOW (CFS) aaa *100.00 NEEDLE OPENING (PU} Or er rnnenan=°0.0 PMECH (MW) ---=0.0 BRAOLEY itS (HZ)20,00016.00012.0008.000014:42DEC051989BRADLEYPARAMETERS14.00018.000TUE,10.000TIME4.00002.00006.00000.0 1988 WINTER PEAK.KENAI AREA ISOLATED.COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD. BRADLEY W/30 SEC NEEDLE.REVISED OROOP &TIME CONSTANTS. PICK UP 7MW OF LOAD AT SOLDOTNA AT T FILE:WP88U02X.CHN NET TURBINE HEAD (FT) =0.5 SECONDS. 1200.0 Meer erersrccs x 900.00 TURBINE FLOW (CFS) 1600.0 ert +100.00 NEEDLE OPENING (PU) 1.0000 @-----------°0.0 PMECH (MW) 150.00 -7-TT 0.0 BRADLEY 115 (HZ) 60.500 x, poe 20.0004.00006.0000-12.00016.0000.010.00014.00018.000TIMETUE,6.60002.000015:52BRADLEYPARAMETERSDEC051989 1988 WINTER PEAK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LORO.5BRADLEYW/SURGE TANK &10 SEC NEEDLE.REVISED OROOP 3&TIME CONSTANTS.PICK UP 3MW AT T =0.5 SECONDS._ FILE:WP88TO3X.CHN 2 NET TURBINE HEAD (FT)- 1200.0 Mes ee reesees x 900.00 ra TURBINE FLOW (CFS)a1600.0 ease 100.00 wsNEEDLEOPENING[PU) 1.0000 Peer rennmn-n-°0.0 ls PMECH (MW)> 150.00 ------0.0 BRADLEY 115 (HZ) 60.500 -----58.000 J Tl |en 3t}or s @ ';"3 7 |4;riot ry} *ry 's :rt}S -+|'"<s :ite :;I 2 .1@f °L_:ite _|° ,t u * rt :i!: -:|_/c {ve)*(1 I 3 !Oo Le +||: ndwy}8 _ad _|s vr = 7 'rane 2 =ro 3 tee YN mo v8 Ne,e\',YC 2 -'\'\.4s nad \\\!2 -\'I S j ' 7 r fy 'Io J 'il a 2 fm]BRADLEYPARAMETERSTIME 1988 WINTER PEAK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD. BRADLEY W/SURGE TANK &10 SEC NEEDLE.REVISED OROOP PICK UP 7MW AT T =0.5 SECONDS.&TIME CONSTANTS. FILE:WP88U03X.CHN NET TURBINE HEAD (FT) 1200.0 Mer erer cerca x G00.00 :TURBINE FLOW (CFS) 1600.0 rrr TTS 100.00 NEEDLE OPENING (PU} 1.0000 @----------->0.0 PMECH (MW) 150.00 --7-7 7 0.0 BRAOLEY 115 (HZ) 60.500 ------4]58.000 a +-+--¢I Pia ||| :| :®ro -ae _ :;:| :r |x :'|_L _ae' troad '\ i | 1 \ 1 _-_DEC05198916:11TUE,BRADLEYPARAMETERS10.0002.00004.00006.00008.00003.00005.00007.00009.0000TIMEt.00000.0 1988 WINTER PEAK.KENAI AREA ISOLATED. COOPER ©16MW &BOTH BRADLEY UNITS SUPPLYING KENAI LOAD.nog)BRADLEY W/SURGE TANK &10 SEC NEEDLE.REVISED DROOP 5&TIME CONSTANTS.PICK UP 10MW AT T =0.5 SECONDS.ud FILE:WP88U04X.CHN aTo= cc NET TURBINE HEAD (FT)|"ge 1200.0 Mores sees x 900.00,Ye TURBINE FLOW (CFS)a O 1600.0 alee +100.00 toa ad NEEDLE OPENING (PU)ff 1.0000 re °0.0 uw PMECH (MW)|=a 150.00 -----0.0 |= BRADLEY 115 (HZ) 60.500 -------58.000 a .=. ';«TT CTT |g :'1]S :i {-2]!ti 3 a :Poo!74 :H 1 | 't o :i |3pm:i +|"= i \ ?7 >4 3__!\- -ae: - s = : one =3 {3 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska September 24,1990 TO:TCS Members FROM:David Burlingame,Manager,Facilities Engineering 7S SUBJECT:Bradley Lake PMC Meeting -September 21,1990 During the last PMC meeting the attached synopsis of the two TCS meetin was distributed to the committee. The PMC directed the TCS to perform the following: Provide a list of cases in which the frequency excursions without the braking resistor rise above 61.5.Hz.The maximum frequency'rise and duration experienced and the maximum amount of Bradley Lake power that could be expected without the braking resistor if the frequency rise was held to 61.5 Hz or less. Provide a list of cases with the braking resistor in service ina realistic control scheme to determine the maximum power output of Bradley Lake,the resultant transient overfrequency and the number of different operating scenarios under which this overfrequency occurs. The PMC also directed the TCS that the final decision on the configuration of the Kenai/Bradley Lake system will be made by the PMC and that the TCS should not rule out the use of braking resistors at this time. Following your review,I will forward the request to AEA/SWEC to supply the requested cases prior to the next TCS meeting. Please advise of any additional concerns or comments File 411 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska September 20,1990 TO:Bradley Lake Project Management Committee FROM:David W.Burlingame,Bradley TCS representative fe SUBJECT:Technical Coordinating Subcommittee (TCS)Report The following is a brief synopsis of the 2 TCS meetings held sincethelastmeetingoftheProjectManagementCommittee(PMC): July 19,1990Meeting Stability Studies -It was agreed that any stability studies required to ensure the proper incorporation of Bradley Lake intotheRailbeltsystemwouldbeincludedaspartoftheproject. The committee adopted a list of stability cases intended to assess the interim operating limits of Bradley Lake.The interim periodistheperiodbetweenthetimeBradleyLakebecomesoperationaland the time when stability aids such as SVS installations are installed on the system. SCADA -A listing of points to be connected to the Chugach RTU was distributed and approved. Soldotna -Bradley Lake Line Homer Electric Association,Inc. (HEA)stated the line is scheduled to be completed by April 1, 1991. Unit Tripping -The committee agreed to allow tripping of one or both of the Bradley Lake units if tripping of these units would allow a higher operating capacity for the plant and improve thestabilityandpostfaultconditions. Series Capacitors -Stone &Webster Engineering Corporation (SWEC)recommended against the use of series capacitors in the Kenai 115 kv systen.The recommendation was made due to the concern for subsynchronous resonance on the Kenai.The recommendation was unanimously adopted. Braking Resistor -SWEC stated they would not endorse the use of the braking resistor used in the manner proposed by PowerTechnologies,Inc.(PTI).SWEC believes the scheme is too complicated and may never work as intended.SWEC also expressedtheirconcernovertheuseofbrakingresistorsingeneralbasedontheirdiscussionswithpersonnelatthetwoinstallationsinNorth America. Bradley Lake Project Management Committee TCS Report September 20,1990 Page 2 Stability Criteria -HEA and Chugach agreed to allow the transientoverfrequencytoriseabove61.5 Hz,if no detrimental effects to turbines or consumers was encountered. Generator Stabilizer -SWEC recommended the purchase of a Fuji power system stabilizer as opposed to the previously specifiedGeneralElectric(GE)or PTI digital stabilizer.The Fuji stabilizer is analog and does not have the control characteristics used in the stability studies but is considerably cheaper than either digital stabilizer.The Committee accepted the recommendation provided the use of the Fuji stabilizer does not result in any decrease in the capacity output of Bradley Lake. August30,1990 Meeting Generator Test Reports -The committee generally agreed the test reports performed by PTI were done very well.The tests brought upseveralquestionsinregardstotheperformanceofsomeunitsin the system.SWEC was directed to put the Kenai generation testreportsinthesameformat. Bradley Lake Procurement and Testing Schedule -The schedules for the start-up and commissioning of the Bradley Lake units and thesubsequentinstallationoftheSVS_systems was reviewed.Basically,the start-up of Unit #2 will commence in May with on-line testing starting sometime in June.The unit is scheduled to be turned over to the utilities for operation July 1,1991 andscheduledtogocommercialSeptember1,1991.Unit #1 will follow approximately 30 days behind Unit 2's schedule for testing andutilityoperationwithcommercialoperationalsoscheduledfor September 1,1991. The installation of the SVS systems is optimistically scheduled forJune1992,with utility acceptance in January,1993. Braking Resistor -SWEC recommended against the installation of a braking resistor at Bradley Lake.The recommendation was based on the use of unit tripping and frequency excursions up to 63 Hzfollowingislanding.The recommendation was adopted by thecommitteependingthereviewoftherequiredstabilitycasestoshowdeletionofthebrakewillnotresultinanycapacityreductionsforBradleyLake.It was felt unit tripping for theBradley Soldotna Line and the frequency excursions to 63 Hz will allow Bradley to operate at 90 MW in the fall of 1991. Bradley Lake Project Management Committee TCS Report September 20,1990 Page 3 The TCS recommended including the costs of dual porting the HEA Diamond Ridge RTU as part of the project cost.Dual porting willeliminateaCPU-CPU link which would have been required between the Chugach and HEA SCADA systems.The cost of the dual porting hasbeenquotedbyHEA's RTU vendor as $30,974.00.The recommendation will require PMC approval. The PMC also needs to approve the reimbursement to Chugach of $95,441.09 for relay additions required at HEA's Soldotna Substation for the operation of Bradley Lake.The expenditure was approved by the TCS in December,1988 and was thought to have beenapprovedbyPMCbutnoresolutionhasbeenfoundintherecords. The original Technical Coordinating Committee (TCC)resolution was for the installation of subject relays was not to exceed $115,000. Since the TCS meetings,HEA has indicated there may be some problen with frequency excursions previously adopted by the TCS. DWB/pn DWB4-65 -"\pr-- POWER TECHNOLOGIES,INC.ONE SIERRAGATE PLAZA SUITE 3408 ROSEVILLE.CA 95678 916 783-3566 TELEFAX 916 783-2086 TELEX 145496 October 15,1990 Mr.Marty Gustafson Stone &Webster Engineering Corp. Denver,Colorado Subject:Bradley Lake Stabilizer Options PTI/SWEC 092-L Dear Marty: We have completed the comparison of an electrical power input stabilizer such as Fugi's and an accelerating power input stabilizer such as PTI's ST/1.Our findings are presented below.Some observations beyond the direct comparison are also presented and may be of use in evaluating stabilizer options. Most simulation cases are based on a system with two SVSs,one at Kasilof,and one at Daves Creek.Stabilizers are not represented on the SVSs.The Kasilof SVS has a 45 Mvar underexcited limit unless otherwise noted.Capacitors at Soldotna are not switched off in any cases.Motors among customer loads are modeled by static load models as in all recent studies.Bernice generation is off-line unless otherwise indicated.Cooper generation is on-line in all cases. UWAr 4eyyrns ee 4 ole To ensure a close comparison,both electrical power and accelerating power stabilizers are based on the PTI digital stabilizer.When used in the power mode,the digital stabilizer) is functionally equivalent to a typical analog stabilizer.The>"”"4 cower” electrical power stabilizer has a 3 second washout time unless otherwise noted. Fault and Trip of Bradley to Soldotna Line The system will be unstable for many disturbances if stabilizers are not properly tuned and operating at Bradley.Cases 1A,1B, and 1C show the result of fault and trip of the Bradley to Soldotna line without stabilizers,with electrical power Stabilizers,and accelerating power stabilizers respectively. Bradley is at 90 MW,and export is 53 MW in this case.The system is dramatically unstable without stabilizers but shows good damping with electrical power or accelerating power Stabilizers.The results with electrical power and accelerating power stabilizers are nearly identical. CORPORATE OFFICES +1482 ERIE BOULEVARD «PO SOX 1058 *SCHENECTADY NY 12301-1058 ©$18 374.1220 Mr.Marty Gustafson: October 15,1990 Page2 Healthy System Without Loss ofElement The system may also be unstable without being weakened by a line outage if the stabilizers are not properly tuned and operating at Bradley.Case 2 shows sustained oscillations following a "stub fault"at Soldotna with Bradley at 120 MW and the export at 75 MW.These oscillations would be growing at a modest rate if customer motors had been modeled as motors.Though a stub fault was used to initiate relatively large oscillations in this example,the oscillations would likely occur essentially spontaneously,and grow until loss of synchronism causes separation.Electrical power or accelerating power stabilizers at Bradley would control these oscillations well. SVS Contribution Stabilizers on the SVSs should cause the system-intact oscillations to decay over time.However,SVS stabilizers may not be sufficient to provide stability following fault and trip of the Bradley to Soldota line without significant help from stabilizers on the Bradley units. Islanding Cases Disturbances that cause islanding result in stabilizer action because the stabilizers respond to the Bradley electrical power excursions that follow separation.This is undesirable,but cannot be avoided because the stabilizers must be free to respond to somewhat similar power excursions that accompany disturbances such as trip of the Bradley to Soldotna line. Two disturbances.were considered.The first is fault and trip of the Soldotna to Quartz 115 kV followed by trip of the 69 kV line 0.5 seconds later.The 69 kV line is tripped by its relays as the system loses synchronism.The second disturbance is a fault at Daves Creek and trip of the Daves Creek to University line.The first case islands the Kenai with one SVS,and the second islands the Kenai with two SVSs.These cases are labeled 3A and 3B,and 4A and 4B respectively,for cases with electrical power and accelerating power stabilizers.Both disturbances result in overvoltages following separation,and the same Mr.Marty Gustafson: October 15,1990 Page 3 conclusion regarding electrical power and accelerating power stabilizers. The electrical power stabilizer causes higher and prolonged overvoltages following interruption of Kenai export.The accelerating power stabilizer causes just a short duration overvoltage. In case 3A the electrical power stabilizer causes load bus voltages to remain above 115%for 0.9 seconds.In case 3B the accelerating power stabilizer causes voltages to remain above 115%for 0.8 seconds.With the electrical power stabilizer several load bus voltages remain above 110%out to a point beyond 5 seconds.With the accelerating power stabilizer load bus voltages are all below 110%within 1 second,and are all near normal within 1.5 seconds. In cases 4A and 4B the load bus voltages peak near 115%with voltages in the electrical power stabilizer case about 0.5% higher.Load bus voltages are above 110%for 1.0 second with the electrical power stabilizer (case 4A)and above 110%for just 0.7 seconds with the accelerating power stabilizer (case 4B). In case 3C the underexcited range of the Kasilof SVS is increased from 45 Mvar to 60 Mvar to help bring load bus voltages within the 110%criteria.With this 15 Mvar increase in SVS size,all voltages except Fritz Creek are below 1108. Fritz Creek is only slightly above 110%. Case 3D was run to show how special tuning of the electrical power stabilizer tuning can shorten the time the load bus voltages spend above 110%.Voltages are unchanged in the early portion of the run,but drop below 110%at about 3.7 seconds rather than at some point above 5 seconds.The change was to set the stabilizer "washout"for 1 second instead of 3 seconds. This will not measurably degrade performance at the dominant 0.9 Hz Bradley oscillation mode.It will significantly reduce Stabilizer effectiveness at lower oscillation frequencies,but Mr.Marty Gustafson: October 15,1990 Page 4 this should be acceptable because troublesome lower frequency modes have not been observed in the studies.Because 3 seconds is a typical washout time for electrical power stabilizers, special stabilizer tuning instructions may be necessary to have al second setting. One cause of the extended high voltage in the electrical power stabilizer cases is "windup."Because we do not have detailed information on the Fuji stabilizer design,we have assumed it has no special features to limit windup.A sophisticated design with features to limit windup would modestly reduce the time that the electrical power stabilizer remains on ceiling following separation of the Kenai from Anchorage.Accelerating power stabilizers are not subject to windup because the input signal is more transient in nature. Background information on windup is provided in an attachment to this letter. Deflector Movement Cases were run to assess the impact of deflector action on voltage.These cases might represent modest load rejections that cause slow deflector movement (large overspeed and rapid deflector movement is covered in the previous section).In these cases the deflectors are run in 35 MW over a period of 10 seconds,and then back out over another 10 seconds.Case 5A has a electrical power stabilizer and 5B has an accelerating power stabilizer. The electrical power stabilizer is at its positive ceiling during the run-in,and negative ceiling during the run-out.It thus causes voltage at Bradley to move up 10%during the run-in, and down 10%during the run-out.A 3 second washout time was used in this case.A 1 second washout time would give the same result for this ramp rate because it too would hold the Stabilizer at its ceiling.However,at lower ramp rates the 1 second washout would result in proportionately lower stabilizer output (i.e.,about 1/3 that of a 3 second washout). Mr.Marty Gustafson: October 15,1990 Page 5 The accelerating power stabilizer causes only about a 1% deviation in voltage for the same deflector movement. System Without SVS Near term operation without SVSs or future operation with an SVS out of service was considered.Cases for Kenai-Anchorage separation between Daves Creek and University without SVSs and with electrical power and accelerating power stabilizers are shown in 6A and 6B respectively.Bradley is operating at 70 MW, export is 29 MW,and Bernice is supplying 23 MW.Though the case represents separation above Daves 'Creek with both SVSs removed,it is also a close approximation to separation below Daves Creek with just the Kasilof SVS out of service. The electrical power stabilizer causes maximum load bus voltages about 1%higher than the accelerating power stabilizer,and causes voltages to remain above 110%beyond the 5 second time of the simulation. With the accelerating power stabilizer load bus voltages fall below 110%about 1.3 seconds after the disturbance. Power Schedule Change The cases 7A and 7B were run to examine the effect of changes in Bradley power caused by an AGC system.Case 7A is for the electrical power stabilizer,and 7B for the accelerating power stabilizer.In both cases Bradley power is ramped at the maximum rate as limited by the 90 second needle time.With a electrical power stabilizer voltage is biased 3%while the needles are moving.Voltage is increased while the needles are moving in,and decreased while the needles are moving out.The accelerating power stabilizer causes only a very small and temporary change in voltage (about 1/2%for 1/4 second). Deflector for Stability Enhancement Present plans do not call for the use of the deflector to enhance stability.However,if this function is ever added to the Bradley governor,the effect of it on the Bradley stabilizers would be important.Two cases were run,9A and 9B, Mr.Marty Gustafson: October 15,1990 Page 6 the first with a electrical power stabilizer and the second with an accelerating power stabilizer.In both cases Bradley is at 90 MW and export is 53 MW.The deflector is run in about 20 MW upon trip of the Bradley to Soldotna line. The cases show the lowest voltage during the first-swing is about 2%lower with the accelerating power stabilizer than with the electrical power stabilizer.This is because the accelerating power stabilizer does not require washout,and thus is more responsive to the initial power excursion. The cases also show better damping with the accelerating power stabilizer.The electrical power stabilizer output is biased up because of the large change in electrical power that it sees in the first second as the deflector runs in.This windup lasts for several seconds and biases the stabilizer output so that the full symmetrical variations from subsequent oscillations are not available to improve damping.The effect on damping is modest but measurable.A 1 second washout would reduce this effect. The accelerating power stabilizer does not respond to the change in electrical power,but to the difference between electrical power and turbine mechanical power,so sees only a momentary input and does not wind up. Unit Tripping Unit tripping is presently planned as the means to provide Bradley stability when Bradley power is above 90 MW.Stabilizer response following trip of a Bradley unit at 60 MW is shown for electrical power and accelerating power stabilizers in cases 8A and 8B respectively. There is little difference in the performance of the two stabilizers. Stabilizer Protective Circuits It is essential that the Bradley stabilizers remain active under all conditions in which Bradley remains connected to the Anchorage area and Kenai exports are significant.As shown in Mr.Marty Gustafson: October 15,1990 Page 7 these studies,disconnection of the stabilizers could easily result in growing oscillations and loss-of synchronism.This, in turn,could cause a blackout in the Kenai,and may result in load shedding in the Anchorage area.These concerns also apply to situations where Kenai export is not high,but could be increased by loss of load in the Kenai or by loss of generation in the Anchorage area that causes Bradley power to increase. For the stabilizers to be reliable,their protective circuits must be set carefully,and must not respond to temporary conditions.For instance,if the stabilizers are removed by backswing overvoltages following fault and trip of the Bradley to Soldotna line,the system will lose synchronism seconds later as oscillations increase. In this study protective circuits have been assumed to not operate under any of the conditions studied.Both overvoltage and overspeed stabilizer cutouts could conceivably be set to reduce the extended contribution of the electrical power stabilizer to overvoltages.However,tight settings that would do this would have to be checked carefully to be sure that they will not remove the stabilizers when they are needed.Also,the cutout circuits would have to be designed to automatically restore the stabilizers to service when the voltage or speed drop below a safe threshold (such as 5%above normal).This automatic restoration is essential to ensure the stabilizers are active when the system is reconnected and export restored. Making this an operator action would add to the operator tasks necessary to restore the system,and thus slow that restoration or increase risk of further system failure when the system is being restored. Summary Effective stabilizers at Bradley are absolutely essential to system stability.Without the stabilizers,instability can occur under normal system conditions and without a disturbance. The performance of electrical power and accelerating power stabilizers is essentially the same for conditions which demand Mr.Marty Gustafson: October 15,1990 Page 8 accurate stabilizer response to maintain stability.Both stabilizers have the tuning range necessary to provide good damping. The electrical power stabilizer will cause or aggravate overvoltages following separation of the Kenai from Anchorage, and will cause voltage variations when an operator or an AGC system changes the Bradley power level.Voltages will rise when power is increasing,and drop when power is decreasing. The contribution to overvoltages following separation are quite measurable.If the Kasilof SVS is designed to provide the same overvoltages following Kenai-Anchorage separation with electrical and accelerating power stabilizers,it will be about 15 Mvar larger if a electrical power stabilizer is used at Bradley.If an accelerating power stabilizer saves 15 Mvar of SVS dynamic range,it will reduce the cost of the SVS by $200,000 to $300,000. A number of other disturbances and conditions were studied.In no case does a electrical power stabilizer have an advantage over an accelerating power stabilizer.In almost every case the accelerating power offers either better damping or less impact on voltages. The critical role of stabilizers is demonstrated in this analysis.Stabilizers should be operating at all times,and must be operating when export levels are high.Stabilizer reliability is thus very important. Observations Stabilizers must be properly tuned to be efiective.Many utilities check and re-tune stabilizers on an annual basis. This is particularly important for analog type stabilizers because they are subject to drift and well-intentioned tampering by operators. Problem diagnosis and replacement parts are also critical to stabilizer reliability.Replacement parts must be readily Mr.Marty Gustafson: October 15,1990 Page9 available and easy to replace.In some designs,this effectively means total stabilizer replacement.Whether a few parts are replaced or a complete unit is replaced,in the case of an analog stabilizer,re-tuning is necessary. The tuning process is complex and requires the proper instrumentation and specially trained personnel with an understanding of feedback control systems and the stabilizer theory and application. Significant changes to automatic voltage regulator and excitation system settings can require re-tuning of the stabilizer. The Kenai system will go through relatively frequent and large power,voltage,and frequency excursions that may trigger 'Stabilizer protective circuits.Many of these circuits remove and lock-out the stabilizer on the assumption that a failed component in the stabilizer is causing the problem.It is essential that such circuits only operate when necessary,and return stabilizers to service automatically and promptly when the conditions is corrected if the problem is not caused by the stabilizer itself. Sincerely, ;Vives om fe GallrrisonK.Clark Manager,Western Office Electrical Power Stabilizers and Windus The extended period of overvoltage in the cases with electrical power stabilizers has two causes.The overvoltage is sustained as long as the Bradley electrical power is changing,and also continues for some period after the power has settled at a new value.The overvoltage while power is changing is a necessary byproduct of a electrical power stabilizer.A electrical power stabilizer has no way to know if power is changing because of a change in prime mover power,or because of a change in system load,and thus must respond to both.Though this is a necessary byproduct,its effect can be reduced somewhat by judicious tuning of the electrical power stabilizer.Using a smaller washout time constant about halves the duration of the extended overvoltage. The second electrical power stabilizer design characteristic that causes overvoltage to continue after the large power excursions have subsided is called "windup."All electrical power stabilizers exhibit some windup,but the amount will be limited in a sophisticated design.The next four paragraphs provide some background on windup,and are provided for the reader interested in the details behind the windup problem. Windup is shown along with the diagram of the basic elements of a electrical power stabilizer in the sketch below.The basic elements are gain,a differentiator,and a time lag.The gain (K)sets the magnitude of the voltage bias to be applied to the voltage regulator for a given variation in power at the input. The differentiator (s3)causes stabilizer output when the power is changing.The lag (1+s3)compensates for the "lead"inserted by the differentiator (note that the output of the differentiator becomes large as soon as the ramp starts).A 3 second washout is used in this example.The concepts are the same for a shorter washout time constant. LIMITERGAINOFF,LAG POWER i |BIAS TOK$5 ss VOLTAReaATER The power is ramped at a constant rate over a period of 3 seconds in this example.The gain and differentiator produce a large output while the power is rising.The lag delays the signal and also smooths it.However,the output of the lag not only builds slowly,it decays slowly.It thus takes several seconds to decay after the input power is no longer rising. Because the lag output is larger than is allowed to reach the voltage regulator,the stabilizer output is flat at its maximum level until the output of the lag drops below the upper limit of the limiting circuit.As can be seen,a 3 second ramp results in stabilizer output at its upper limit for about 5 seconds,and output decays to zero only after another 3 or 4 seconds. Windup can be limited by placing limits on the integrator in the lag element.The lag element integrator is stopped when its output reaches or slightly exceeds the level that would push the stabilizer output to a limit.The signal at this stage is thus ready to begin dropping as soon as the output of the differentiator drops below its present level.Ina very sophisticated design,all integrators are "clamped"when the output signal reaches its limit.The last stage integrator symbol in the Fuji stabilizer block diagram indicates that this stage is limited,but the first three stages are apparently not limited.Limiting the last stage reduces the windup somewhat, but does not eliminate it. In an analog type of stabilizer such as the Fuji unit,the power supply voltage may limit windup to two or three times the output limit (the signal cannot rise above the voltage supplied to the operational amplifiers).This will help,and would result in slightly shorter overvoltage periods than shown in our simulations. Because an accelerating power stabilizer responds only to differences between generator electrical power and turbine mechanical power,windup is not a problem.The differences between electrical power and mechanical power are always short- lived or very small,and thus there is no sustained signal to cause windup.The PTI digital stabilizer does not limit windup because it is usually used in the accelerating power mode where windup is not a problem.If windup does become a problem,anti- windup logic can be readily added to the intermediate stages of the digital stabilizer (intermediate stages would be clamped when the stabilizer output reaches either limit). Harrison ClarkOctober15,1990 WUC ( 55%KEN LOAD.S53MW EXP @ D.C.90MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/=-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE NO STABILIZER FILE:53B90D35.CHN DAVES CREEK 115 KV_VOLTAGE 1.3000 womens >0.3000 ANCHOR POINT 115 KV_VOLTAGE 1.3000 Me seerecesee x 0.3000 KASILOF POINT 115 KV_VOLTAGE 1.3000 freer +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 eetteetaated °0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 ---7 0.3000 BRADLEY 115 KV_VOLTAGE 1.3000 4 0.3000 >---ngJ en ree repr Serpeetoemoepeteree I _PT rs TFromeresweereeeeeesetei 4.00005.00004.50003.00002.00001.0000FRI,2.50003.5000TIME1.50000.500012:19OCT121990KENAIVOLTAGES i ( 55%KEN LOAD.S3MW EXP @ D.C.9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE NO STABILIZER FILE:53B90D35.CHN UNIT 1 SPEED,3 HZ/DIV 12:20ESOCT121990UNIT1VAFRI,27.000 Meeseceecccs x 3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 ede +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000.Ge cerwceere=°-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ----175.0 ACCELERATING POWER,30 MW/DIV 70.000 --------=230.0 ---eeeeeeeewpeeateeeeeaepeeeeee5.00002.00003.00004.00002.50003.50004.5000TIME1.5000 t ( 55%KEN LOAD.53MW EXP @ D.C.90MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+3S5MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE ELECTRICAL POWER STABILIZER FILE:53B90D01.BIN DAVES CREEK 115 KV VOLTAGE 1.3000 ee >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mosse eee x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 -------+0.3000 {QUARTZ 115 KV VOLTAGE }1.3000 eee eel °0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 -----o 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 -----a 0.3000 |in |3 eo a o .Qo -(A : So S =_/2° ° S So = o fo] =8 l 1 i !t |° i I =E <_T °FRI,2.50003.50004.5000TIME1.50000.500011:47OCT121990KENAIVOLTAGES ( 55%KEN LOAD.S53MW EXP @ D.C.90MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/ 45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE ELECTRICAL POWER STABILIZER FILE:53B90D01.BIN UNIT 1 SPEED,3 H2Z/DIV 27.000 Meeccesceccs x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 ere +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 rawr re errenebd -20.00 MECHANICAL POWER,30 MW/DIV 125.00 ------t -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &a -230.0 i TIT TT ::|'!.4 :|.wn J '': ='1 . ': - ''8|''x ° | '3|:+:a bd '3 :|¢,: 4 '2 =|';:_ 1 .|im L : '. g .'\.4 A .[=] =|'1 :° :wom T..) I ';x |?4 : =|se 77 - \!..|'t 'f=] |ws.bet,:= -\TT °_/°|'7s 4 :s '1 : |!Po |'\x ed |_ --!°- _-"-_+--”" is pra ¢H 'i=] \!: '\-"A |aan Smanne/ -'!_'' uv i |rae ----! ¢J ene .ws 7 °o.1]ran =|»Ps 11:47"ESOCT121990UNIT1VP?FRI,2.50003.50004.5000TIME0.5000 L ( 55%KEN LOAD.S5S3MW EXP @ D.C.9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/=-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE ACCELERATING POWER STABILIZER : FILE:53B90D01.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 Roses >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Moves esses x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 eel +0.3000 QUARTZ 115 KV_VOLTAGE 1.3000 Pree anraaae °0.3000 SOLDOTNA_115 KV _VOLTAG 1.3000 So 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 ----0.3000 meal -:0412OCT121990KENAIVOLTAGESFRI,5.00002.00003.00004.00001.50002.50003.50004.5000TIME1.00000.5000 {( 55%KEN LOAD.53MW EXP @ D.C.9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+3S5MVAR/ -45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY, ACCELERATING POWER STABILIZER FILE:53B90D01.CHN UNIT 1 SPEED,3 H2Z/DIV TRIP SOLDOTNA LINE 27.000 Heres ererces x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 reer rrr +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Com crer renee e -20.00 MECHANICAL POWER,30 MW/DIV 125.00 ---7-1 -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 .-_-_-_-_-----s -230.0 |j i |] |'' H é |'ee I -J \4 t|'' NLo| |'+ 4 ° 7)f , =|_ Lj{'w \XV |' e .' =|'t -| |'{ !|of sx! =|;7 - -_t j '\ 1NS7 = !;aer]--_ad|\ 1' 't : i :\x |mo jor]ry \ t \4 -|'\- |>ite|i --l \;- |''é|ween”1 ![Se |eee]§.00004.00003.00002.00001.0000raeN& a! k o fon)a> el eq 4 HBHoz a?) -_ x fu So o o w So o o wn Ped o s wma ee oe oe °o wo - oOo oa f=] wn ° '' 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA,NO LINE TRIP NO STABILIZER FILE:75B12E37.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 Rese sess >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Meee eee eee es x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 eos ee +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 erated °0.3000 SOLDOTNA_115 KV _VOLTAG 1.3000 -----os 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 os 0.3000 -ed 5.00004.50004.00003.00002.0000FRI,2.50003.5000TIME1.50000.500014:04OCT121990KENAIVOLTAGES 55%KEN LOAD. ( 75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA,NO LINE TRIP NO STABILIZER FILE:75B12E37.CHN UNIT 1 SPEED,3 HZ/DIV 27.000 Messeres x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 Saale ieiieetiatiaes +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 alee eat e -20.00 MECHANICAL POWER,30 MW/DIV 125.00 -_oe ero -175.0 ELECTRICAL POWER,30 MW/DIV ------200.0 iT TT ||: t |?1 |é ; /'.-_m4q]'t \i}. |'.': |\;x I '+™ 'i |>t '|4 /| |/i - co !c|H t |'' . .{. |'\1 :- AY .;x '.|'4 \;! | n ! |/1 ;: 'I .|;!:_ \. '|. |'': '{. '|\,x |t t|$;é4/|/1 - g 1 |:I a 1 i %e,1 - '\|'' l '1 1 ,Ly |am |l |,|5.00004.50004.00003.00002.00001.0000014:05OCT121990UNIT1VAaSFRI,2.50003.5000TIME1.50000.5000 f 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/=45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA 115,TRIP QUARTZ 115 &69 LINES, ELECTRICAL POWER STABILIZER FILE:75B120E22.BIN DAVES CREEK 115 KV VOLTAGE 5.00004.50004.00001.3000 wee emma >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Merc r sre rces x 0.3000 KASILOF_POINT 115 KV _VOLTAGE 1.3000 eerrere +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 occ reocese=bd 0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 -_On 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 :eo 0.3000 +¢ <7 ||| 1 e1? t 4 ta - 1 4 +1+>',° I f44 G =I 4 qi S 14 '31'")i}® 1 H 1 t N)1 q 14 1 4 1 _| 1 ¢tf ”+213!o4 - roy re? ¢ s o - & \ ' \ 5 Pa \= Pad --Tere rl ls _11:48OCT121990KENAIVOLTAGESFRI,3.00002.50003.5000TIME2.00001.5000 55%KEN LOAD.75MW EXP @ D.C. ( 120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA 115,TRIP QUARTZ 115 &69 LINES, ELECTRICAL POWER STABILIZER FILE:75B120E22.BIN UNIT 1 SPEED,3 H2/DIV 27.000 Mere crsrcrces *-3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 reer +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 'tor cerenrencebd -20.00 MECHANICAL POWER,30 MW/DIV 125.00 ---175.0 ELECTRICAL POWER,30 MW/DIV 70.000 c-_-___-----5 =-230.0 |tT of]7]x 3 i :°|8g = |\:a 1 t .-_- I ':° Z |*S bo :+ |+|:'j .b=4 af '1 :S |\1 :a ©'': ” |: |3 Le |'|:aebe'.m |1 1 x |H g __-|+i _|4't .N 1 {°}\!: [:Ly !:s :s -I 'i .=A '/:/\;: y |:: =r |° ¢ \|S |wen':ol.8''a _. - |'an g {es '_oe a :"1° |'i |'' Ly :||2 11:49OCT121990UNIT1VAFRI,TIME5S ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA 115,TRIP QUARTZ 115 &69 LINES, ACCELERATING POWER STABILIZER FILE:75B120E22.CHN 12:06OCT1219905.00004.50004.00002.00001.0000DAVES CREEK 115 KV_VOLTAGE 1.3000 wre ewes 0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mee erceccere x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 leans +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 mn rr reerrnnbd 0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 ------- -1 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 OS 0.3000 a t || ad ».-- ysHit!° :+pe: :a * $.s |' :os 'oat .°,bs -:$i -ple ;vir: 'road;cd yt: Le :va - iy & f ToS tee - nl Tl -FRI,3.50001.50000.5000KENAIVOLTAGESTIME 55%KEN LOAD. 4C/3P FAULT AT SOLDOTNA 115, ACCELERATING POWER STABILIZER FILE:75B120E22.CHN UNIT 1 SPEED,3 HZ/DIV ( 75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. TRIP QUARTZ 115 &69 LINES, 27.000 Mercer ccrccce -3.000 STABILIZER OUTPUT,.1PU/DIV 0.7000 emer -0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Cree rncerecn=-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ---1 -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 eo=-_-_-_--s8 -230.0 rT TIF |-- {'i[]'1|'{ !I |'1 ' ||L}. |H +:7 '':]¢ '1 : -'\!.-_- '|:||: !!Po -' e eebo I '!x 'rool'"t. ]¢t ||}a {; 'ot cs)|'a -e |' _--?a 1 -'3/”_e--:°a .y t i x _. y H } . - 7 '\bd iS' '1Pt_”/ -/eer"?Cm am -_- "eL 7] |-2?7 T=nie) |ss,Vee eee<r,roaeel"s,"m4 - 't'' | 'Ly a L 5.00004.50004.00003.00002.00001.00002.50003.5000TIME1.50000.500012:06'ESOCT121990UNIT1VAFRI, 4C/3P FAULT AT SOLDOTNA, f ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-60MVAR SVS @ KASILOF. FILE:KAS60 DAVES CREEK 115 KV_VOLTAGE TRIP QUARTZ CREEK LINES -->1.3000 es >3.3000 =FRITZ CREEK 115 KV VOLTAGE }1.3000 Merce reeseces x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 eres +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 Oa neonnenne=°0.3000 SOLDOTNA_115 KV_VOLTAG 1.3000 -----=0.3000 BRADLEY 115 KV VOLTAGE 1.3000 -----0.3000 |TT ||T a ) "hing : ||»NY-|C bg $¢-4 |<34i;}"=> 'xj Va)&-_>37 !|s !VU Hh \ !>4 Y)cLi!}o 1 -[:]iI ,- rtiH »af 3sri =1 t ww _ vlog -1 ¢ 'h =ad g - ;i}PY "5.00004.50004.00003.00002.00001.000011:27ocT151990MON,2.50003.5000TIME1.50000.5000 ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/--20MVAR SVS @ DAVES CRK &+35MVAR/-60MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA, FILE:KAS60 UNIT 1 SPEED,3 HZ/DIV TRIP QUARTZ LINES 27.000 Meececcccces «-3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 eee +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Paseeonnnnn-°-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ------175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &4 -230.0 Log "t 7 ra)|y toil il |: !: "9 |: =:_ I '. : l '\::1 . |'1 * ='1 ' - J i ' 'l . 4 : besearm>J e -_ P |: )'\:§ '|° -_|'|: ''y !* |'+ '| _}+I - 'i ,4 !: !. a ': 1 : = |\{: |'t : 7 '}./'': i/x -_ ° -H + t 1Mi '/ =/ower e em aN --'am|”z= 'me --I *s,TT ee - 4 ||; i '] |Ly '||§.00004.50004.00003.00002.00001.00002.50003.5000TIME1.50000.5000OocT15199009:33 i ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT SOLDOTNA,TRIP QUARTZ 115 &69 KV LINES ELECTRICAL POWER STABILIZER,1 SEC.WASHOUT FILE:J:\STAB\OUTB\75B120E22 DAVES CREEK 115 KV VOLTAGE 13:14MON,OCT1519901.3000 wees sree ee >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Meee ceereres x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 eeocce +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 @ aa enen-----°0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 -----4 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 ---As 0.3000 7 ||Td | Sk:5)olma) -Bay 5 -_™I}!9 J.»-_? xi " !\y Sa3 a"4 'a \fr _1!Hoa WV) Wit =ou - {. |ie? t 5 |rote fy 3=I i ¢ _] L .Hy sy d 1 L)l:; .as a - 4 mae @ onee 5.00003.00004.00002.50003.50004.5000TIME2.00000.5000 55%KEN LOAD. 4C/3P FAULT AT SOLDOTNA, ELECTRICAL POWER STABILIZER, FILE:J:\STAB\OUTB\75B120E22 ( 75MW ( EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. TRIP QUARTZ 115 &69 KV LINES 1 SEC.WASHOUT UNIT 1 SPEED,3 HZ/DiIV 27.000 Kerr eececens x -3.000 STABILIZER OUTPUT,.1PU/DIV 0.7000 eer +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 @assaseasrae °-20.00 MECHANICAL POWER,30 MW/DIV 125.00 -----At -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &>)-230.0 °+x °i [tT ;: |H ':8 = |'i : -<< \!: |1 !:'i °sI\*g --i}4 .--ey° \* |¢!:?1 :s4-_--!:3=_|Hf '°-_-!. ®t ':m |'i]:'t .° '' :5 ={'i :-°' :” |'x\t . +:S So _|+|”'|a 1 { 'i]°|'':3 -': \ /';:1 /'{.2 /*8 ,7 't - rs 7 ''° 'oni---7°°A S - ,-¢"se ©{_7ST 4 |.yr o 1 oO wo foe aI , . *''|'' | Ly |oo:|||c OCT15199013:15MON,TIME 55%KEN LOAD. é ( 7SMW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF.3 ep)4C/3P FAULT AT DAVE CREEK,TRIP UNIVERSITY LINE = ELECTRICAL POWER STABILIZER s es) FILE:75B120E40.BIN rt DAVES CREEK 115 KV_VOLTAGE_o 1.3000 were eee >0.3000}&raANCHORPOINT115KVVOLTAGE"s1.3000 |Mreeee eee x 0.3000 N KASILOF POINT 115 KV VOLTAGE eo i1.3000 SSS +0.3000 ©&QUARTZ 115 KV VOLTAGE °fo}1.3000 ea 25-55-5555 °0.3000 we |SOLDOTNA 115 KV VOLTAG ee}1.3000 ----0.3000 BRADLEY 115 KV_VOLTAGE 1.3000 C =)0.3000 :+opith!||3Pedy"3t'-_iy ydean 8 by orga |+ if faa :.|1%tea 2 - 1]iF 3 3 'ya qa +-e :re |/|+4HsoeUYDhan >S .|i _j ” rr |” itis °i {oy ° :Pseotg ° =|bapa =) aesth : =bs;a8send )uefrm)& th :-_!i _J° ara N of . oO a 3 = E a" a atAx 8 :°o -|at STIs 8 j oS { ||L |x i] ( 55%KEN LOAD.75MW 4C/3P FAULT AT DAVE CREEK, ( EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. ELECTRICAL POWER STABILIZER FILE:75B120E40.BIN UNIT 1 SPEED,3 HZ/DIV TRIP UNIVERSITY LINE 27.000 Merercesccce x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 rere * -0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Pas seneesne °-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ---- -1 -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 _-_-_-_-5 -230.0 f tT?TT T=J g '1 :o|:" ': | |;- l ,; {'1 :i i :S | |'*3 ; \* '! \:'it . =|t u :™ [5]''|.1 1 !° :: |'{.°oi\:S|l '\.° !!:mn | ,of 4t =|+| _\! fob'1 o'!°|\S ),1 'on '|: ]'I : 1 . }x /'4 - '! 1f o ?|oS /8 '\-i \ i \ '! , .-Ze "=.Smee --bmeewennne2.50003.50004.5000TIME1.50000.500011:50OCT121990UNIT1VAFRI,ES ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT DAVE CREEK, ACCELERATING POWER STABILIZER FILE:75B120E40.CHN DAVES CREEK 115 KV_VOLTAGE TRIP UNIVERSITY LINE ©3000 em ne ee me me 0.3000 ANCHOR POINT 115 KV VOLTAGE ©3000 Be we we ss es 0.3000 KASILOF POINT 115 KV VOLTAGE -3000 Perrerre 0.3000 QUARTZ 115 KV VOLTAGE ©3000 eee nmeaea 0.3000 SOLDOTNA 115 KV VOLTAG -3000 ----0.3000 BRADLEY 115 KV_VOLTAGE : -3000 |0.3000 |||rantretryrataniioae -aeeeeSeeoMOSSLye5.00004.50004.00003.00002.0000FRI3.50602.5000TIME0.500012:07OCT121990KENAIVOLTAGESUU 4 55%KEN LOAD.75MW 4C/3P FAULT AT DAVE CREEK, ACCELERATING POWER ( . EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. STABILIZER FILE:75B120E40.CHN UNIT 1 SPEED,3 HZ/DIV TRIP UNIVERSITY LINE 27.000 Heres reccce -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 "Keer -0.300 FIELD VOLTAGE,4 PO/DIV 20.000 Cremereesene -20.00 MECHANICAL POWER,30 MW/DIV 125.00 --o_o Ch -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &-230.0 ||t|,|+3 '!=tl'1 no 8 = |H |a '{-"-| |'\ t So Lj t So|'\E |'+™ - 4 t . :: v 1 .4'ryLe'\:8'l :7}O«]l 7 ; 'i :l '|:S =|'':3 '1 :- I '1 x :roo+3 i a =|¢|8 '.N '” 'ol ':° 'ot °|\|4 'ran |ae 4 * 7 7'. eo eT 8 o ”.ad/ra Sn : ]a '! ¢1 ,2 '|° i \ae '\ '\ \1 ° of 4 S * )©oemeeeeeOCT12199012:07UNIT1VAFRI,TIME"ES 55%KEN LOAD.S3MW EXP @ D.C. ( S9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/ 45MVAR SVS @ KASILOF. SLOWLY INSERT AND REMOVE BRADLEY UNIT DEFLECTORS ELECTRICAL POWER STABILIZER FILE:53B390D34.BIN DAVES CREEK 115 KV VOLTAGE 1.3000 weer erm ee aa 0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mseerrccccce x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 werner +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 @oennnrennen °0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 --9.3000 BRADLEY 115 KV VOLTAGE 1.3000 -_-_-_-_--s 0.3000 t-te -albyt | sli: rt Z eeuh:_ HlHi: t Ce / of? atrit7td -J ¢|- "4att2ci6«oof _i _ '|it .t1itnH ae ''1 youd J '1)iT gtgu '| \ "4il [||_|20.00016,00012.0008.00004.0000aep)2 fx=©>fon)a 4 fon)"8N edSapoOoma a_ [a fu o f=] o 2 fo]Oo o = Oo eg oO =7 ee oO Go to) oS ry oS fo} a o " 55%KEN LOAD.S3MW EXP @ D.C. { S9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. SLOWLY INSERT AND REMOVE BRADLEY UNIT DEFLECTORS ELECTRICAL POWER STABILIZER FILE:53B90D34.BIN UNIT 1 SPEED,3 HZ/DIV 27.0000 SMEeenes -3.000 STABILIZER OOTPOT,.1 PU/DIV O,.FOQG ame ge cae ee -0.300 FIELD VOLTAGE,4 PU/DIV 20.0000 mw nnnman 20.00 MECHANICAL POWER,30 MW/DIV 125.00 ------175.0 ELECTRICAL POWER,30 MW/DIV 70.000 fo -230.0 ¢°H4'|\ |'!|(] ='i - |'! '1 |'i '1 t it -8 -- '+ 'f¢t 't L ''\ _|\a --! \i \4 ' " \_- - \a poo\H V}-}+1 - 4 /!t ,!= \ - / ___.'1 '4 ™ / i ; 1 -;;_ :lé a \ '\-.--- , e-/5 tow --4 F . |' ,|i L Po |20.00016.00012.0008.00004.000010.00014.00018.000TIME6.00002.0000OCT12199011:56UNIT1VA”"ESFRI, {( 55%KEN LOAD.S3MW EXP @ D.C.QS9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/=45MVAR SVS @ KASILOF. SLOWLY INSERT AND REMOVE BRADLEY UNIT DEFLECTORS ACCELERATING POWER STABILIZER FILE:53B90D34.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 was see >0.3000 ANCHOR POINT _115_KV VOLTAGE 1.3000 Mere cere eee x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 ieee +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 eensennanae °0.3000 SOLDOTNA_115 KV VOLTAG 1.3000 ----s 0.3000 BRADLEY 115 KV VOLTAGE 1.3000 -------0.3000 |||||20.00016.00012.0008.00004.0000=Notome|>a a"8N toon|a io©Oa HG(a2 fu oa oe to] 2 oe Oo ° o eg co "ee eo o o Qo wo So o o c=] " ( 55%KEN LOAD.S3MW EXP @ D.C.9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-4SMVAR SVS @ KASILOF. SLOWLY INSERT AND REMOVE BRADLEY UNIT DEFLECTORS ACCELERATING POWER STABILIZER FILE:53B90D34.CHN UNIT 1 SPEED,3 HZ/DIV eehhdekate27.000 Mercere cess x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 we +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 So ere eseen=-°-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ---175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &5)-230.0 ||H ||_}' = ] 1 3 - |\|'1 '{ i \ -'- 't '1.' \'' __t t -_\!' \'5' ;\! 7 \\4,q\/a =}\ -¢d !3 |' =|'t _J /; :!/' t _ /' t ond !+ \¢ = 4 /'a!-_- /' ! /s 20.00016.00012.0008.00004.000012:15OCT121990UNIT1VA'S10.00014.00016.000FRI,TIME6.00002.0000 :( CASE C.WINTER PEAK LOAD.30MW EXPORT @ DAVES CREEK. KENAI GEN:70MW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER. 4C/3P FAULT AT DAVES CREEK,TRIP UNIVERSITY LINE ELECTRICAL POWER STABILIZER -FILE:29B70B40.BIN DAVES CREEK 115 KV VOLTAGE 11:59KENAIVOLTAGESFRI,OCT1219901.3000 we mo meeewe >Oo. ANCHOR POINT 115 KV VOLTAGE 1.3000 rrr x o. KASILOF POINT 115 KV VOLTAGE 1.3000 ------>o. QUARTZ 115 KV VOLTAGE 1.3000 SPerewoeeenecreca °o 0. SOLDOTNA_115 KV _VOLTAG 1.3000 ---0. BRADLEY 115 KV VOLTAGE 1.3000 |-_-_-o 0 ne [1 | rf -i'an : =i '\am ;!\S f |4 {i i =i | a |Sofa : -_|f!;5.00002.00003.00004.00002.50003.50004.5000TIME1.50001.00000.5000.0 ( CASE C.WINTER PEAK LOAD.30MW EXPORT @ DAVES CREEK. KENAI GEN:7OMW @ BRADLEY, 4C/3P FAULT AT DAVES CREEK, ELECTRICAL POWER STABILIZER FILE:29B70B40.BIN UNIT 1 SPEED,3 #2Z/DIV 23MW @ BERNICE &16MW @ COOPER. TRIP UNIVERSITY LINE -_-eeeieeeCO,Ubeweeeee27.000 Re ew se ess x -3.000 STABILIZER OUTPOT,.1 PU/DIV 0.7000 am mmm em ee cme +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 (0 Ge mere rae oe °-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ----7-1 -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 eE77-_-_-_-_-_--o8 -230.0 ||ry Tf 7]=- i : |': '!, = ; '':|!!:,|]* ='L -|; |+|:'|: s '\: -I . -I ;:]]'1 : 1 I '| ; --I ':- 1|'1 * '4|'I Le |>t _| 4 ! ]H ! |'{ =_| |'!. ]';|t '*--4 . /H t $1 '' t i} -/\ \ i §.00004.50004.00003.00002.00001.0000.012:00SOCT121990UNIT1VAFRI,2.50003.5000TIME1.50000.5000 ; CASE C.WINTER PEAK LOAD.30MW EXPORT @ DAVE KENAI GEN:7OMW @ BRADLEY, 4C/3P FAULT AT DAVES CREEK, ACCELERATING POWER STABILIZER FILE:29B70B40.CHN DAVES CREEK 115 KV VOLTAGE ( S CREEK. 23MW @ BERNICE &16MW @ COOPER. TRIP UNIVERSITY LINE 1.3000 wre msm ees 3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Meeveeesneneecn 3000 KASILOF POINT 115 KV VOLTAGE 1.3000 errr 3000 QUARTZ 115 KV VOLTAGE 1.3000 Soc e were eeee 73000 SOLDOTNA_115 KV _VOLTAG 1.3000 -7 7 -3000 BRADLEY 115 KV_VOLTAGE 1.3000 8 3000 oe val i \§| -isn - I. ' ! -|--5.00004.00003.00002.00001.0000owSfx]we ODmG©oFa4] Nnpal 4N wee.hoooma .HGfod fu eo fo] Oo " oS So o wn a" o oOo 42 Nn AH Ex oa So So wm 0.5000 f 1 ' CASE C.WINTER PEAK LOAD.30MW EXPORT @ DAVES CREEK. KENAI GEN:7OMW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER. 4C/3P FAULT AT DAVES CREEK,TRIP UNIVERSITY LINE ACCELERATING POWER STABILIZER FILE:29870B40.CHN UNIT 1 SPEED,3 H2/DIV 27.000 Moore errr x 3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 ea nintedbedien +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Oo nc eenren=-°-20.00 MECHANICAL POWER,30 MW/DIV 125.00 ------175.0 ELECTRICAL POWER,30 MW/DIV 70.000 ----3 -230.0 +x o||tT |;:: ]'':we'I :° -3 Po 4:|'1 : '':'So 't .oO - |.8 |'+:+ ': i :1 .°'t . =i :é'i ;sa I :i : ||!:: -J '!:-* !|! ;8 -|¢1)8 '- j '17 S Ss !a 1 .4 !N onan |s I :: ;a |x ° 'an .a -_ I :+:7 - :| |¢1 {°po :i f \3 =|Yee wee .n'I :a_i |:': |;': '.°o|it |||-|x OCT12199012:18UNIT1VAFRI,TIMEES (( 55%KEN LOAD.53MW EXP @ D.C.SOMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. RAMP UP BRADLEY UNIT POWER SCHEDULES AT MAXIMUM RATE, ELECTRICAL POWER STABILIZER FILE:53B90D00.BIN DAVES CREEK 115 KV_VOLTAGE 11:51Roe r ee eee >0.3000 ANCHOR POINT 115 KV VOLTAGE Mosse eeecees x 0.3000 KASILOF POINT 115 KV VOLTAGE een +0.3000 QUARTZ 115 KV VOLTAGE Saeense cease °0.3000 SOLDOTNA 115 KV VOLTAG ----0.3000 BRADLEY 115 KV VOLTAGE --as 0.3000 |'|OCT121990KENAIVOLTAGES8.000012.00016.000oo6.000010.00014.00018.00FRI,TIME4.00002.0000 55%KEN LOAD. {( 53MW EXP @ D.C.9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. RAMP UP BRADLEY UNIT POWER SCHEDULES AT MAXIMUM RATE, ELECTRICAL POWER STABILIZER FILE:53B90D00.BIN UNIT 1 SPEED,3 HZ/DIV 27.000 Moree rrcecrcs x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 reer reree +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Sor encernan=°-20.00 MECHANICAL POWER,30 MW/DIV 125.00 -----175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &1 -230.0 4 |.oomTyTF|Ti g \'):4*{:': = 't . i t :-_- ;I : t i}. '{°°o - !*S |'+:|e t !: \+t : (t . \'': ='i].- [*)\'. \': t}'':S --\'i :*'i . 1 K 1 * 1 '+!; H i : =\>°!:- '.a4 '4 . {;' ; Fy)'i :2;3 _H {:-_° |'{' ° '1 :|| Z !3 !t .--|'4 : |; Jt|=4 '!S -|'}_J° @ ''|\ 'l ; Le 'I 1 | ' 1 oAS|4 vet |*o 10.00014.00018.000TIME6.00002.000011:511OCT121990UNIT1VAFRI,ES 55%KEN LOAD.53MW EXP @ D.C. {f 9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+3SMVAR/-45MVAR SVS @ KASILOF. RAMP UP BRADLEY UNIT POWER SCHEDULES AT MAXIMUM RATEACCELERATINGPOWERSTABILIZERFILE:53B90D00.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 wrasse eas >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mosse sec ees x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 eed +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 oa assrsseee °0.3000 SOLDOTNA_115 KV _VOLTAG 1.3000 -----=0.3000 BRADLEY 115 KV VOLTAGE 1.3000 ----0.3000 |||20.00016.00012.0006.000018.00014,00013:08ocT151990MON,10.000TIME2.0000 (( 55%KEN LOAD.53MW EXP @ D.C.S90MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/ 45MVAR SVS @ KASILOF. RAMP UP BRADLEY UNIT POWER SCHEDULES AT MAXIMUM RATE, ACCELERATING POWER STABILIZER -° FILE:53B90D00.CHN UNIT 1 SPEED,3 HZ/DIV 27.000 Mere rercccns bad -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 -eerrereoro +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 ton errrrrcre °-20.00 MECHANICAL POWER,30 MW/DIV 125.00 -_-o--175.0 ELECTRICAL POWER,30 MW/DIV 70.000 V7 -230.0 1 or TT |r : |'.4 :c H ':"o t é .oS = |'I '_|2 |'1 .= :':|'t . 't .° L_ |*S |'+:19 I . |+: j ':s _\I :°\'].™='j : '1 :I 'j .° 'i :S _-\\:Tn \'x - ;g --\>::-¢ 4 ;;; - Fy)|';;3 = |'i :_|e |'|'ro] 'I : |'I :o = ||:*: |t {© |; 4 1 ° -seEt]'{|'' |'I ° '|= -|!'_!|2 '!|t ! |'i tl |yf '|=12:09OCT121990UNIT1VAFRI,TIME'ES { 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/ 45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE, ELECTRICAL POWER STABILIZER ; FILE:75B12E36.BIN DAVES CREEK 115 KV VOLTAGE TRIP UNIT 1 1.3000 weer eres >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Keorecccrcses x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 weer +0.3000 _QUARTZ 115 KV VOLTAGE 1.3000 aeeetateaeetated °0.3000 SOLDOTNA 115 KV_VOLTAG 1.3000 ---------0.3000 BRADLEY 115 KV VOLTAGE a 1.3000 8 0.3000 | |||J |aadIBreasSATAweee2eyee'ate5:-oOtr=a5.00004.50004.00003.00002.0000FRI,2.50003.5000TIME1.50000.500012:02OCT121990KENAIVOLTAGES if f 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP.+25/-20MVAR SVS @ DAVES CRK&+35MVAR/-45MVAR SVS @ KASILOF.4C/3P FAULT AT BRADLEY, ELECTRICAL POWER STABILIZER TRIP SOLDOTNA LINE,TRIP UNIT 1 FILE:75B12E36.BIN UNIT 1 SPEED,3 HZ/DIV 27.000 Meer eercrecss x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 lene + -0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Sarr rer resembd -20.00 MECHANICAL POWER,30 MW/DIV 125.00 -7-a 175.0 ELECTRICAL POWER,30 MW/DIV -_-_-_-_-----o -200.0 +&PP]| :J !'f \I L}t --_ '| 'J 'rei-: H rad : 7 'c . +f : 'i . "an : '. -AY . \too .'. 1 l . ': ae 3777 : .17 7 - :- \1 *'.+ ,wae el 1 j -= '1 '\ -!_ SO - '! \! ;'.. 'sy Te x11:- '\ o \ '\ wore'---!|a oleae an] 'i ,1 '\ sel 1 _ ae ay,4 v 4 '/ t | '\!fe a1=|[EESTI |7 5.00004.50004.00003.00002.00001.0000012:03OCT121990UNIT1FRI,3.50002.5000TIME1.50000.5000"5VA' ( 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE, BREECTRECAL POWER STABILIZER TRIP UNIT 1 ACCELE RATING FILE:75B12E36.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 reece cen:>0.3000 .ANCHOR POINT 115 KV VOLTAGE 1.3000 Mevccecccccs x 0.3000 KASILOF POINT 115 KV VOLTAGE 1.3000 patentee +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 Pons reccrn °0.3000 SOLDOTNA_115 KV _VOLTAG 1.3000 -----0.3000 BRADLEY 115 KV VOLTAGE 1.3000 e )0.3000 -_-othwr>mamon§.00004.50004.00003.00002.00001.0000FRI,2.50003.5000TIME1.50000.500012:23OCT121990KENAIVOLTAGES 55%KEN LOAD.75MW EXP @ D.C. f 120MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE,TRIP UNIT 1 SEBCTRICAS POWER STABILIZER ACCELERATING FILE:75B12E36.CHN UNIT 1 SPEED,3 H2Z/DIV 27.000 Ke eeeccecres x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 heer +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 , Pee c crew eenn °=20.00 MECHANICAL POWER,30 MW/DIV 125.00 -----175.0 ELECTRICAL POWER,30 MW/DIV 100.00 OO =200.0 |TT rT]|i Tt 3 i t :3|H } :a' |. = 'i |:\7 \\ |1 \ '1 x 3 = |8|'+bd '¢|54 ra14\1 =|\sy - LY oe |''---'1 |eo __-!: S -|-"--7":8 4 wT x m '\: |+ --| y "TT Tas a 1 |4 \ |'\a!\3 |per een sa'!on PO)|:|\\ s Il"sy nl ee -4 -|4 ' |+' '\° 4 _--!_-!2 -|pO mT > é 1 é '{ \1 ss 1 a ee won 77 a)- '/ '/ '\ ;\fp,sf Fee neers ns ° r=||oa.|-=|co 12:232.50003.50004.5000TIME*0.5000FRI,OCT121990"0UNIT1VA: 55%KEN LOAD.53MW EXP @ D.C.SOMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE,INSERT DEFLECTOR ELECTRICAL POWER STABILIZER FILE:53B90D1A.BIN DAVES_CREEK_115 KV VOLTAGE 12:01OcT1219901.3000 wrest mse had 0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mercere ccrens x 0.3000 KASILOF POINT 115 KV_VOLTAGE 1.3000 --w ene +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 b aeaieeteteeeteaelbd 0.3000 SOLDOTNA_115 KV VOLTAG 1.3000 --C-nn 0.3000 BRADLEY 115 KV_VOLTAGE 1.3000 &a 0.3000 KENAIVOLTAGESFRI,|||ocSe"Seqex ?-.ot?*oeszlottoBSpet=any\:a5.00003.00004.00003.50004.50002.5000TIME1.00002.00001.50000.5000rt 55%KEN LOAD.S3MW EXP @ D.C. 4C/3P FAULT AT BRADLEY, f 9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. TRIP SOLDOTNA LINE, ELECTRICAL POWER STABILIZER FILE:53B90D1A.BIN UNIT 1 SPEED,3 H2Z/DIV INSERT DEFLECTOR 27.000 Mee eeecceces =3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 weer 0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Perneernnn--20.00 MECHANICAL POWER,30 MW/DIV 125.00 -------i -175.0 ELECTRICAL POWER,30 MW/DIV 70.000 &-230.0 -¥an TT |g !g|\\a |'t |vs,Moe '7 eo|+° |!ro 3 |.°7 ee er =< '\ ?\ t 14'\ 1|'1 - '1|'\i s we oI',3 |'7s e 'TJ"|ue?a |'#777 '!|¢{'- \''|''2 |'}3 '!- J YM eee i : |:---- 77 W200 TTT -|r t a ié|\° f )g '\an pet '1 '; ]See -_--oeBO et ay/a ;a [ee|\/t ! 7 ;\ |ram ---? 1 teen,osrrcr {°2.50003.50004.5000TIME1.50000.5000"ESOCT12199012:01UNIT1VAFRI, 55%KEN LOAD.S53MW EXP @ D.C.S9O0MW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/-45MVAR SVS @ KASILOF. INSERT DEFLECTOR4C/3P FAULT AT BRADLEY, BSECTEITCAD POWER STABILIZER TRIP SOLDOTNA LINE, ACCELERATING FILE:53B90D1A.CHN DAVES CREEK 115 KV VOLTAGE 1.3000 wre memes >0.3000 ANCHOR POINT 115 KV VOLTAGE 1.3000 Mere eeserceers x 0.3000 KASILOF POINT 115 KV VOLTAGE_ 1.3000 ween +0.3000 QUARTZ 115 KV VOLTAGE 1.3000 steiner e 0.3000 SOLDOTNA 115 KV VOLTAG 1.3000 -7-no 0.3000 |BRADLEY 115 KV VOLTAGE|1.3000 3 0.3000 |||5.00004.50004.00003.00002.00001.0000FRI,2.50003.5000TIME1.50000.500012:21OCT121990KENAIVOLTAGES 55%KEN LOAD. ACCELERATING 53MW EXP @ D.C.S9OMW @ BRADLEY &16MW @ COOP. +25/-20MVAR SVS @ DAVES CRK &+35MVAR/ 45MVAR SVS @ KASILOF. 4C/3P FAULT AT BRADLEY,TRIP SOLDOTNA LINE,INSERT DEFLECTOR FSECERECAD POWER STABILIZER FILE:53B90D1A.CHN UNIT 1 SPEED,3 HZ/DIV 27.000 Roe eecccccce x -3.000 STABILIZER OUTPUT,.1 PU/DIV 0.7000 eer ecc +-0.300 FIELD VOLTAGE,4 PU/DIV 20.000 Oem nerecene=°=20.00 MECHANICAL POWER,30 MW/DIV 125.00 . "------175.0 |__ACCELERATING POWER,30 MW/DIV 70.000 B ) 230.0 <2 --+xTT?Fo a \: |\. .\: |es erie Oe ' .."se .- |:77 y : |:i t . '\: |i *bob eer --t77? ] o*ror|H,4|N.|- |ws me - {ie||!©'. |'':- ' ;\x :o!awd °|.ev al |o | -'1 po' |pT |\ \:{| Se +™ '7|-\ ft 1\- !sso.' |a = /i /1 V4 '' 7 7 '\ /\||e=2 ee eye ee ee {he,esrscpso |5.00004.50004.00003.00002.00001.00002.50003.5000TIME1.50000.500012:22OCT121990UNIT1VA''ESFRI, COPY STONE &WEBSTER ENGINEERING CORPORATION ee:TCritikos/Chron NABishop/JbBk RPWynn JYale DNix HZanjani MGustafson 2950r July 9,1990 Mr.D.R.Eberle J.0.No.19239.21 Alaska Energy Authesity WP26A 701 East Tudor Road Anchorage,AK 99503 INTERIM OPERATING STUDY SCOPE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY Stone &Webster Engineering Corporation (SWEC)and Power Technologies Inc. (PTI)have reviewed the May 8,1990 letter from CEA regarding the Interim Operating Study for the Bradley Lake Project.In order to prepare a definitive scope to meet the utilities requests,a number of assumptions must be made,and additional information is required.In addition,there are several cases that we believe are not significant and could be deleted or modified to reduce the study cost.It is requested that the TCS confirm the assumptions contained in this letter,provide the additional information and criteria requested and review the cases we have recommended be deleted.In the interest of time we have sent copies of this letter to the members of the TCS for their review and request their response at the next TCS meeting tentatively scheduled for July 19,1990.The following assumptions are proposed: 1.Relay modeling will include only the Kenai generator protection and line impedance relays on the main trunk lines between Bradley Lake and University (these are the relays that could be subject to nuisance trip during severe swings). 2.The utilities stability criteria requirements,from our understanding of the CEA letter and from previous studies,include the following: e Bradley and all other generation affected by Bradley plant loadingmustremaininsynchronism(except where the disturbance directly islands the system). e Voltages at load buses must remain under 115%and not go above 110%for more than 0.5 seconds. °Voltages at load busses must remain above 80%of pre-disturbance level during all post-disturbance power swings.All voltagesshallsettleabove95%of pre-disturbance levels. Mr.D.R.Eberle é July 9,1990 Page 2 °Kenai frequency must remain above 58.5 Hz and under 61.5 Hz during and following disturbances. e Load shedding must not greatly exceed the loss of import or loss of generation (applies to both Kenai and remainder of Railbelt system). °Line distance and overcurrent protection must not be operated by power and voltage swings following disturbances. e Generator protection (out-of-step,loss-of-synchronism,reverse power,over/underspeed,excitation limiting)shall not operate during or following disturbances. °Unit tripping (at Bradley)is not to be used to improve stability. °Loss of load during faults shall be recognized in stability cases. Where fault type,placement on the line,and reclosing are not specifically given in the test cases,a three-phase fault without reclosing will be used and the worst-case end of the line determined. All reclosing,if utilized,will be three-pole reclosing. All test cases will be run with two Bradley units on-line (for most stable operation and highest Kenai reliability). The study will be done with the Bradley Junction to Soldotna line in the model.Then,as an option,all steps necessary would be repeated to establish the maximum Bradley power output without the Bradley Junetion to Soldotna line. Maximum Bradley power level will be bracketed by running stability cases at 5 MW increments.Where the stable case of any stable/unstable pair appears marginal,we will adjust the estimated Bradley power limit downward to ensure a several MW margin,and assure stability. In addition to the TCS verifying that the above assumptions are proper,we have the following questions regarding this study: l. 2. Are any additional model changes necessary other than adding the Xenai area relays and restoring today's conditions in the network? Which generators should be redispatched,or added or removed as Bradley Lake power is adjusted up or down from the 12 load/generation base case scenarios tabulated in the CEA letter?It should be noted that the redispatched generators will also need to accommodate changes in losses as Bradley power is changed. Mr.D.R.Eberle July 9,1990 Page 3 6. Since the Diamond Ridge to Homer 69 kV line is radial,would not only four cycle near-end clearing be of concern in the study?(see test case 18) Should the Bernice Lake to Soldotna 69kV line be open or closed in all of the test cases? Some of the test cases as presently suggested would threaten stability of other plants or areas (e.g.,Bernice Lake in test case 6 and Fairbanks in test case 19)more than Bradley.Must Bradley Lake and the most severely affected plant/area both remain stable if adjusting Bradley Power-has little or no effect on the stability of the most severely affected plant? The attachment to the CEA letter calls for a check of Transient Recovery Voltage (TRV)for each breaker that is called on to operate inthelistoftestcases.If this is intendedto include each faultinterruptioninthelist(19 cases),this part of the study would be extensive.We also note that having Bradley Lake on-line would only affect the TRY of breakers relatively close to 3radley.A TRV check of each of 19 breakers would require about 60 days.Is this study required for the interim operating period from when the units are available for generation and the SVS is on-line? PTI is using the impedance value in the Railbelt Data Book for the University to Daves Creek line.Is this correct for this study? It would be a great benefit to relocate the spare 138/115kV transformer from Teeland to University to operate in parallel and thus reduce the impedance.Can this be done before testing starts? Based upon PTI's review of CEA's letter they have proposed the FollowingstudymethodforTCSreview: Set up the 1991 conditions as outlined. Update dynamic models based on recent machine tests and add relay models. Set up all stability test case response files (includes calculating unbalanced fault data,setting up all requested plots). Select the load/generation scenario that appears most likely to restrict Bradley power.Run those test cases which are likely to be most restrictive,and identify permissible Bradley loading levels.Run all other test cases for these Bradley loading levels to confirm the most restrictive disturbance conditions. Mr.D.R.Eberle July 9,1990 Page 4 5.Determine the maximum Bradley loading for each of the other scenarios using the most restrictive disturbances identified in 4 above. 6.Optionally,rerun cases as necessary to determine maximum BradleypoweroutputwiththeBradleyJunctiontoSoldotnalineremovedfrom service. 7.Prepare draft and final reports. A review of the cases presented in the CEA letter indicates that some could be eliminated,thus reducing study costs.The presence or absence of powerflowfromAnchoragetoFairbankswillnothaveasignificantinfluenceon permissible Bradley operating levels during the interim period.The Kenai generation combinations can likewise be reduced.For the peak and light load conditions,we recommend the following Kenai generator combinations: a.)Bradley only,b.)Bradley and Cooper,c.)Bradley,Cooper,and Bernice.For combinations where Bernice Lake units are on line,we proposeonlytwoBerniceLakeunits.This provides a more pessimistic scenario due to lower inertia and short circuit levels then with three Bernice Lake units on line.We propose the following changes to the cases outlined by CEA. Case 2 -Eliminate reclosing.Voltages and phase angles on islanding will most likely swing too far to allow reclosing at Daves Creek. Case 3 -Eliminate.Case 5 is a more severe case. Case 6 =Eliminate the 69kV line closed condition.The loads around Bernice Lake will trip on low voltages for a fault on the 115kV line,the status of the 69kV line most likely would not matter. Case 7 -Eliminate.Case 5 is a more severe condition. Case 8 -Eliminate delayed reclosing.If the system can service high speed reclosing,subsequent delayed reclosing should also be stable. Case 10 -Eliminate 115 kV line closed condition.CEA has stated that this line will most likely be operated open.The more severe case is with the 115kV line open. Case 11 -Eliminate.See case 10 comments. Case 12 -Eliminate 115 kV line closed.See case 10 comments. Case 13 -Only look at tripping a Bradley Lake Unit.This representsthelossofthelargestKenaigenerator. Mr.D.R.Eberle "( July 9,1990 Page 5 Case 15 =Delete.This is an Anchorage area problem that will not effect Bradley Lake Loading. Case 19 =Delete.See comments Case 15. It should be noted that study of the three Bradley governor modes is presently under way as part of PTI's current Task 3,work and thus need not be addressed in this study.The governor modes affect only frequency control when the Kenai is islanded.They play no role in the dynamics during and following disturbances that cause islanding. This study is expeeted to have an order of magnitude cost of approximately $45,000.To redefine the maximum Bradley Lake power with the Bradley Junction to Soldotna line out of service will add approximately $20,000. The TRV study will cost from $75,000 to $90,000. Upon receipt of responses from the TCS to the above assumptions and .questions,we will prepare a proposal fer the revised scope of the Interim Operating Study.If you have any questions,please call Mr.John Yale at(303)741 -7433. WZ Deputy Project Manager NAB/JY/TRO cc:DBurlingame (CEA) MYerkes (ML&P) SMatthews (HEA) SHaagenson (GVEA) JHall (MEA) JAnderson (Seward) HClark (PTI) REAR VIEW ">SECTION A-A £RONT VIEW INNER FRONT View ux.ploDE STACK 2 *AW-CT @ @ yan my @l -((ge-_|BZ |ee rh tfc th aga jet 4,™viensacaie El y/NY ™+:ase=lF PCB tor4;__/7 |aE a 23,-PSS a al ;=}{t).|-!vol-s ar<Ol8 fb cla 3}je Se |.-£9}:2.__HlTe: .=i ee>1":. :=e}>4 ELI CE |1).10 N-|=wyvc}gps gh 4 i Cetiia]|ea els i the1Gor|-}-°i _. 7]Oe ,ode ade a tmiF pinay "-t ”eoaee|ees Ba i >_teew |e"ot ak =I bh:FE ;(-p fsPY)enaf |37 ale.icHotaespo**'sis r =ei_C,itr ali bak -staase gu -iy Rit }fs fil NH]ft +t gsHINSor|S besotoe too CF |be ||'EG €9 BO ec ||{E of Be alo Bop . .."a -A 1 RA asI|=x :aco alltin| H a:Sone TH Tae, r-k-I I :1 a ce |+(thafl=ara isr eee ry ole 1 e ee rteseh entcae [veL-f-3 ibs dj Hl ms 4 oes ee |;#-1---j |-=°--ae____yl mi |TOTRT #5tJ (ti 0;;3}svnias,L fant ire,TO ¥S Tae }|s2s9 0.99"ax a |Bedcan(10)oi p.0 62"600)[TINAL DRAWING |ro AUX.RYH ; :ASSEMBLY ORAWING OFautaygoutsurAtOr?aut.nt gon Aura boxe aue.Ay goxs AVR CUBICLE Tle FEren 10 DUG NG 19349274 Fos ->-=oa rors |moos |vince ONIRACT WO.2890033WHEOETARFCuNDEONoeao>|or Tat oe |oe Ce ala cou . '_"ee |PSS Papo Pp BRADLEY LAKE HYDROELECTRIC POWER PROJEC "se os -ne |oe we |oe ALASKA PO¥ER AUTHORITY ry ps '\a ”br]T lfEeeWesesis|4 -si},cd geet-5 ns fh tspeesapg Hedcetol ss aay wos .ryEl?eras x tHER Eh NY eyte ee _"_--<@ .¥351362%"Wey!ahay @e AWW ay Dee Ber wey Oe oe Le Prarances fold a Pen Mere n Ai i |}cdCHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska September 11,1990 TOs TeS Committee Menbers FROM:David W.Burlingame,Chugach Electric Association SUBJECT:Bradley Lake -Technical Coordinating Subcommittee Meeting Minutes August 30,1990 Below are the meeting minutes of August 30,1990: Generator Test Reports -The committee generally agreed the test reports were a vast improvement over the reports supplied directlybyStone&Webster Engineering Corporation (SWEC)for the Kenai generation units.Chugach and Golden Valley have forwarded comments,Municipal Light &Power (ML&P)has not commented on the report.Golden Valley Electric Association,Inc.(GVEA)hadpreviouslycommentedonthetestreportsfortheirunitsandare preparing comments on the Chugach/ML&P test reports. The stability study and procurement schedule for Bradley Lake wasreviewed.Basically Unit #2 will be on-line the middle of June, 1991 for tasting and operating response vith pomercial operationexpectedSeptember1,1991.wi ximately-3dayslaterwithon-line testing and the cane Cone The schedule essentially allows for 60 cays of operation by theUtilitiesonUnit2and30daysonUnit1priortodeclaringthencommercial. cH oe Interim Operating Study -This study is to determine what plancoutputispossibleduringthattimefromwhentheunitsareputon-line until the SVS installations are oneline,approximately oneyear.The scope of studies was agreed upon,and SWEC will forward the cases to Power Technologies,Inc.(PTI).Completion is notexpecteduntilDecember,1990 or January,1991.A draft is due mid-October.The study cases were basically as submitted by theTcsSwiththeexceptionthatSWECdeletedthosecasesforfaultsin the Anchorage area.The deletions were accepted pending SWEC'swrittenconfirmationthereisnotastabilityproblemwiththese test cases. Braking Resistor -SWEC recommended the installation of the brakingresistornotbeconsideredattheBradleyLakePowerPlant.This recommendation was made based on the complexity of the operatingschemerequiredforthebrakingresistor,the utilities decision to allow tripping of a Bradley Lake unit if required for stabilityconsiderationsandanimprovementinperformanceofthegovernor/deflector action by Fuji/Woodward.Allowing the frequencytoriseto63Hzwilleliminatetheneedforthebrakingresistor. Using unit tripping will allow Bradley Lake to operate at its 120MWrating.It is expected that unit tripping will only be requiredforfaultsontheBradleyLake-Soldotna Line. It was agreed by all TCS members to allow frequency excursions upto63HzandtoallowunittrippingofaBradleyLakeunitasa last resort to maintain system stability and voltage/frequencyconditionssolongasthetrippingoftheunitdoesnotadversely effect the systen. SCADA Points List -Alaska Energy Authority (AEA)indicated Chugachhaschangedsomepointsrequiredfortheoperationoftheplant.Chugach will verify what points are required and forward the lisz to AEA. The TCS recommended including the cost of dual porting HomerElectricAssociation,Inc.'s (HEA)new RTU's at Diamond Ridge andSoldotnaaspartoftheprojectcost.This will allow Chugach's SCADA system to talk directly to the HEA RTU without going through the HEA SCADA systen. A draft SVS specification was passed out by SWEC and comments requested by September 15,1990. SWEC will perform the studies required to determine the generation and line constraints on the system during the Bradley Lake generation tests.This testing plan is not expected until January- February 1991. DECEIVE ||-BRADLEY LAKE PROJECT MAR 29 1960TECHNICAL COORDINATION SUBCOMMITTEE (TCS) KA ENERGYALATHORITY|MINUTES OF JANUARY 17,1990 MEETING The meeting came to order at 9:00 a.m.at the offices of the Anchorage Municipal LightandPowerHeadquartersbuilding.In attendance were: Myles C.Yerkes MEA Dave Eberle AEA Tom Small HEA Don Shira AEA Afzal H.Khan -AEA Henri Dale CEA John Cooley ML&P Tim Newton CEA David Burlingame CEA Paul Johnson CEA Vance Cordell CEA Norm Bishop SWEC John Yale SWEC Minutes of the previous December 13,1989 TCS meetings were approved as drafted. The proposed agenda was expanded to include review of secure and emergency transferlimitsiBusiness),and review of a revised project communications plan (NewBusiness). First,the Committee discussed the January,1990 draft "Load Acceptance Analysis”fromSWEC/PTI and recommended the following: A.The first paragraph of page 6 be modified to indicate combustionturbineoperationontheKenaiisonlynecessaryduringperiodsofpowerimporttotheKenaiPeninsula. B.Expand and clarify the spinning reserve table (page 3)to indicateavailableProjectreserveswithandwithoutoperationofareagasturbinesinthe"peaking”mode. Cc.Approval of the modified report including conclusions andrecommendations. Next the Committee discussed PTI Report No.R105S-89,"Dynamic Stability ModelDerivationforUnitsatBerniceLake,Soldotna,and Cooper Lake.”Recommendationsincluded: BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MINUTES OF JANUARY 17,1990 MEETING Page 2 A.Add summary discussion of tests results versus expected results.Emphasize areas where the new model differs significantly from themodelassumedfromfactoryinformation.This work is needed tosupportandjustifytheexpandedgeneratortestingrecommendedbyPTImemorandumofDecember,1989. B.Summarize and discuss any problems or required maintenancediscoveredduringtesting. C.Provide a summary ranking and discussion of which machines in theareaperformthebestinloadacceptanceandrejection. D.Add units to all graphs and clearly indicate the value and units ofscaling. E.Acceptance of the report as modified. Following Committee discussion,AEA agreed to incorporate additional commentsreceivedbyJanuary26,1990 in the final report. Following negotiations with the SCADA vendor,SWEC informed the Committee thatthepricetoprovideDECNETontheBradleyLakeSCADAsystemwouldbe$116,000.This far exceeds the original quote and the SWEC estimate of $40,000.Additionalnegotiationsmayreducethisprice10to15thousanddollars.After considerablediscussion,the Committee delayed any action until a future meeting. AEA presented an estimate in the amount of approximately $50,000 from CEA toprovideamicrowavecommunicationsterminalattheirAnchorageHeadquartersbuilding.This terminal is half of a new microwave unit link to the CEA HeadquartersbuildingwhichCEAfeelsisnece:for control and dispatch of the Bradley LakeProject.This link was approved by the TCS during the meeting of December 13,1989.The committee recommended PMC approval of these costs and reimbursement to CEA,as a cost of the Bradley Lake communications network. SWEC presented control and logic diagrams of a proposed new (third mode)governormodeofoperationwhichwillprovideimprovedresponseaspreviouslyrecommendedbytheTCS.After extensive discussion,the Committee approved the concept andrecommendedmovingforwardtoimplementthisoption.SWEC will beginnegotiationswithWoodward/Fugi to provide this mode and will keep the Committeeinvolvedintheprocess. SWEC presented draft definitions of secure and emergency transfer units (transmissionlines)as discussed during the previous TCS meeting.After considerable discussions,itbecameevidentthatPTImaynotcompletelyunderstandthesignificanceofthesedefinitionsandtheircorrectapplication.In approving these definitions,the CommitteeacknowledgedthattheCommitteeand/or SWEC will need to review future PTI worktoinsurethatthestandardsarecorrectlyappliedandinterpreted. BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MINUTES OF JANUARY 17,1990 MEETING Page 3 Under New Business,SWEC presented an updated schedule for procurement ofstabilityrelatedtransmissionlineequipment.Under very optimistic conditions,theequipmentwillnotbeavailableforserviceuntilmid-1992.The Committeerecommendedthattheschedulebemodifiedtoprovidethefollowing: A.Clear Committee decision or action milestones.Particular emphasisonreview-and approval of the pending performance studies whichwillestablishsystemdesign,and hopefully verify acceptableperformancetotheCommittee. B.Realistic periods for review and approval of critical studies andprocurementdocuments.- C.Anticipated PTI study delays while proposed railbelt turbine testingisconducted. SWEC present the draft Brake Resister Specification for Committee review.TheCommitteeapprovedthedraftdocument.will hold final changes until February1,1990 to allow specific utility comment if desired. Dave Eberle discussed an AEA proposal to conduct performance tests on the railbeltgeneratorsnotincludedinthepreviousKenaiPeninsulatesting.Based on arecommendationfromPTI,SWEC estimates the cost of testing to approximately$180,000.After discussions with the Intertie Operating Committee (IOC),AEA hasagreedtofund50%of this cost as a cost of the Bradley Lake system studies,and theIOCwillfund50%up to the amount of $85,000.In an effort to contain cost,the AEAhaspreparedanRFPfortheseservicestoallowforcompetitiveselectionoftheconsultant.After discussion,the Committee recommended: A.AEA proceed as proposed with the project RFP and cost sharingagreement. B.Involved utilities (CEA,ML&P,GVEA,FMUS)must participate inandagreewithconsultantselection,scope of work,schedule,andcontractualrequirements. C.The final plan and agreements be reviewed and approved by theTCSpriortoexecution. D.AEA delay any system studies utilizing this test information untiltestresultsareavailableforbeneficialuseinthestudies. AEA next distributed a draft schedule for the Bradley Lake Project start-up and testingperiod.The schedule indicated that approximately 60 days may be available forprojectoperationaltesting,that is,continuous on-line operation of the Project todemonstratecorrectandacceptableoperationofallsystemcomponentsinteractingwiththerailbeltpowersystem.After some discussion,the Committee generally agreed that BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MINUTES OF JANUARY 17,1990 MEETINGPage at least 30 days must be allowed for operational testing and 90 days would seemappropriateforschedulingpurposes.Deficiencies or failures during this period couldextendoperationaltesting.The Committee delayed taking formal action until the AEAconsidersschedulingimpacts. As a final item,AEA distributed a revised communication plan from SWEC forcommentasappropriate. The meeting adjourned at approximately 12:30 p.m. SUBMITTED:LZ,La feelie -MYLES C.VICE-CHAIR APPROVED: DAVID EBERLE,CHAIR MY:BB 302A.900124.363 ATTACHMENT #2 TECHNICAL COORDINATION SUBCOMMITTEE SCADA SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES Thursday,March 1,1990 9:O00a.m. (At the Alaska Energy Authority) Attendance: Oscar Johnson Alaska Energy Authority Don Shira Alaska Energy Authority Larry Wolfé Alaska Energy Authority John Zidalis Alaska Energy Authority Vance Cordell Chugach Electric Association Paul Johnson Chugach Electric Association Fred LeBeau Golden Valley Electric Association Maynard Gross Homer.Electric Association Tom Small Homer Electric Association Jim Hall Matanuska Electric Association Robert Day Municipal Light and Power Jonathan Hodges Stone &Webster Engineering John Yale Stone &Webster Engineering The meeting was called to order by Oscar Johnson at approximately 9:00 a.m. I. If. III. Adoption of Prior Meeting Minutes The minutes for the December 13,1989 SCADA Subcommittee meeting were reviewed and approved. Approval/Modification of Agenda New business item C.Revenue Metering Data was added.The Agenda was then approved. Old Business A.DECnet Negotiations The Project Management Committee (PMC)met earlier in the week and recommended that the DECnet'interface be provided.The latest quotation from Landis &Gyr (LGS)is approximately $117,000.SWEC and AEA recommended that it be added as a separate delivery item so as not to affect the powerhouse construction schedule.SWEC will advise LGS of the need for the interface and prepare the required change order. Where the DECnet in interconnected in the loop needs to be determined by the Intertie Operating Committee.b= IV. B.System Status The database development unit has been delivered to AEA''s office in Anchorage.SWEC Engineer,Jonathan Hodges has started development of the database.He will be working in the AEA office until the Factory Acceptance Test, scheduled for June,1990.Landis &Gyr is manufacturing the RTUs and the master.Delivery is scheduled for July 16,1990.The powerhouse construction contractor anticipates beginning installation as soon as it is delivered. Cc.I/0 Lists SWEC previously sent out revised I/O lists.Any comments should tbe given to AEA within a month so that they can be incorporated into the plant design.Any point that is available on the on site SCADA system can be added to the CEA RTU. The on site personnel were discussed.John Zidalis indicated that four people were anticipated.One mechanic,two electrical/meter/relay technicians,and himself. The question was raised as to how problems with the SCADA System or additional point requirements during operations should be addressed.John Zidalis indicated that they should be addressed to AEA. D.Status of CEA Microwave Interface Vance Cordell has coordinated it with Mike Ridge.There have been discussions of who will purchase what equipment. There are two paths being considered.One from CEA headquarters to the National Guard Armory on Tudor road, or to a state building off of Lake Hood.They are doing path studies now. New Business A.Communications Plan John Yale distributed a draft Permanent Project Radio Communications Diagran.It is similar to a previous diagram distributed by AEA however,it removes the temporary telephone links.The utilities were asked to review it,particularly HEA since it shows their maintenance VHF radio system.This document will be modified as the requirements for DECnet and the generator dropping/deflector operation change. B.Database Development System Jonathan Hodges is developing the database.The utilities tJ--, -are welcome to discuss it with him at any time.The completed database will be used for the Factory Acceptance Test.The committed is invited to come to AEA's SCADA room to look over the system after the meeting. C.Revenue Metering Data John Yale distributed a table of the JEM-II meters on the project,and the different parameters that vill be monitored.Comments are requested by Friday,March 3,in order for the order to be placed for the meters by the contractor.CEA needs to have MWH and VARH contacts provided to their RTU.SWEC will provide. Adjournment The meeting was adjourned at approximately 10:30 a.m.with the committee going to the SCADA room to look at the database development unit.ul ATTACHMENT #3 7)ELECTRIC ASSOCIATION.INC. V\fE8 RI one ab 72297 e £907 3385601winnesordceoeA)BK J9GZOQ A RAGE ALASKA 99519-6300 ¢PHONE 907 583.7 982°907-562-0027Mi,Fisf soy ALASKA ENERGYAUTHORITY March 22,1990 Alaska Energy_Authority PO BOX 190869 -x.annAnchorage,AK 99519-0869 Dave Di fee Attention:Mr.Afzal-Khan- Reference:Bradley Lake Hydroelectric Project SVS Specifications Harmonic Measurements PTI Letter of February 2,1990 Dear Mr.Khan: We have reviewed the proposal from Stone &Webster Engineerine Company (SWEC)/Power Technologies,Inc.(PTI)concerning the harmonic levels and voltage unbalances present on the Kenai.We feel the proposal has certain merits and offer the following comments: Chugach Data -The data we have represents approximately one years worth of data at both Quartz Creek and Bernice Lake, unfortunately very little of this time is concurrent between the sites.We feel there is some valuable data in the measurements and is reflective of actual system conditions at the time of the measurements.This information is available for use should theutilitiesortheirrepresentativeelecttoreviewandanalyzeit. Additional Data Gathering -We do not feel there would be a great benefit in having SWEC/PTI take any additional measurements for the harmonic levels.The harmonics present are not constant and vary a great deal from day-to-day and apparently winter-to- summer.The probability of gaining any additional information which is credible is unlikely. We believe the measurements taken will offer a good basis for the SVS specification process and could be used "as a minimum"type statement for bid evaluation purposes,but feel the final responsibility for harmonic measurements and design of the appropriate SVS system should be the responsibility of the manufacturer. Alaska Energy Authority Mr.Afzal Khan Bradley -SVS Specs March 22,1990 Page 2 We recommend the responsibility for the design criteria inregardstothisareaoftheSVSsystemrestwithoneentity,either SWEC or the Vendor.We strongly disagree with any attempttogivesomedesignguidelinesbySWECinthespecificationswhichcanbeloweredorusedforargumentafterinstallationby the Vendor. Please advise if any additional information will be required oriftheChugachdatawillneedtobeavailableforreview. If there are any questions or comments,please feel free to contact me at 762-4610. Sincerely, CHUGACH ELECTRIC ASSOCIATION,INC. OZ A.ly - David W.BurlingameManager,Facilities Engineering DWB/pv DWB4-26 File ¥/e ce:J.Cooley -ML&P M.Yerkes -ML&P T.Small -HEA S.Haagenson -GVEA J.Hall -MEA CORRESPONDENCE DISTRIBUTION ACTION:COPIES: SWE CT ig,Tins Due Date: POWER TECHNOLOGIES.INC.ONG SERNAGATE PLAZA MUTE OB ROSEVELE CA 89679O18783-2008 «=TELEPAL 96 PED-2006 «TELEX 145.08 February 2,1990 Mr.John Yale Stone &Webster Engineering Co. Denver,CO 80217 - Dear John: I called Tuesday (1/30)and found you were out of the office for the week.Since I am goingto be out of the office all next week,I thought I would write and convey some information and concerns.We can discuss them when I return February 12. AS we work on writing the specs for the SVS(s):to be used on -the Kenai system,we are coming to the conclusion that some - new work needs to be budgeted and performed before we issuethefinalSVSspec.When we initially developed the budget and work scope for preparing the SVS specs,we assumed that any system "background”measurements needed to determine harmonic levels and system unbalances in the Kenai would be the responsibility of the SVS vendor and covered ag part of the SVS contract.In recent discussions with Dave Burlingame of CEA concerning existing system characteristics,we have been advised that high harmonic levels and significant unbalance conditions have been observed at Bernice Lake. However,CEA has not specifically analyzed their observationstodeterminespecificharmoniccontentandlevels.All CEA can say for certain is that they have measured high harmonic levels,up to 15%total harmonic distortion,and significant unbalances at Bernice Lake.Based on the Bernice Lake observations,it is very likely that Soldotna and other Kenai locations also have high harmonic and unbalance levels. However,CEA has not quantified the levels at these other locations in the Kenai. This raises concerns as to how to appropriately address this in.the SVS specs.If we tell vendors to bid based on assumedharmonicandunbalancelevelswhicharelow,the bids may reflect prices which ara not sufficient to cover the cost of the needed filters and controls.Moreover,the vendors would be oblivious to potential problems,and we run the risk that they will not address critical issues in their proposals.If we tell the vendors to bid based on assumed harmonic and CORPORATE OFFICES ©1482 SPUR BOULEWUTO*¢PO BOK 1068 ©SCORLNECTADY,NY 12901-1088 ©619 561200 -ay,aa :.weeeeea-.ee eidetmmaaenaes rye 57 :pa = MaR- -14«-980 WED 16120 PTe Pe.as a \y -- Page 2 Nr.John Yale February 2,1990 unbalance levels which ere high and not well defined,the bidsmaybeoverlyhigh.Moreover,without having a better ideaourselvesastohowsignificanttheharmonicandunbalanceconditionis(and particularly what harmonics are present),wewillnaveadifficulttimedeterminingwhetherthevendorshavebidtheproperamountsandtypesofharmonicfiltersforeachSVSinstallation. In order to adequately inform ourselves and to establish a "level and appropriate playing fleld"on which vendors can submit their bids,we propose and recommend that AEA proceedwithaprojecttodetermineandquantifyambientharmonicand unbalance levels at the SVS location(s)in the Kenai. Portions of this project could not be started until we have a final determination of where SVSs will be located.But,in the intervening time,we can proceed with some preliminary analysis and fully outline the project and solicit approval. We have outlined below the logical way to proceed with such a project.. As noted above,CEA has made system measurements at Bernice Lake.They also have a few measurements made at soldotna. These measurements wera made using a portable digital fault recorder (DFR),and the data is stored on disk (about 400 MB worth).In addition,they have a DFR permanently installed at Quartz Creek and have about a year's worth of data from that location.Some of this DFR data,although mainly associated with capturing system disturbances,may adequately reveal system harmonic and unhalances levels.CEA has not analyzed this data to any significant extent and feels that the time required for analysis is more than they can handle.But,CEA is willing to make this data available for analysis by others. As tne first step in a project to quantify ambient narnmonic and unbalance levels in the Kenai,we propose that the existing DFR data collected by CEA ba reviewed and analyzed. This effort should focus mainly on the data for Soldotna and Quartz Creek since these locations are the most likely for an SvS installation.This analysis could be done prior to making a final decision on the number and location of Kenai SVSs. Even if Soldotna or Quarts Creek is not selected as an 6&VS location,the information gained about these two location would be valuable in understanding the harmonic and unbalance problems which exist in tne Kenai.Performing this step first could give us adequate information.and preclude making additional measurements.If further measurements are indicated,this step would better define additional MAR- 14-990 wED 16321 ere ° -"\ -- Page 3 Mr.John Yale February 2,1990 measurements which should be performed.We estimate that this effort would take one man-week and would require travel and living expense for someone to go to CEA's office in AnchoragetoperformthedatareviewandanalysisusingtheirDER software. Following review and analysis of the existing DFR data and thefinaldeterminationofSVSlocation(s),we would outline and define additional ambient system measurements if they are found to be necessary. The attached draft proposal outlines ampient systen measurements which may be appropriate.In addition to harmonic and unbalance measurements,this proposal includesmeasurementsforelectrostatic,magnetic,RFI,TVI,power line carrier and audible noise §levels.These additional measurements may not be essential for development of the Svs specs,but would be a good incremental investment if further ambient system harmonic and unbalance measurements are required.Further,if ABA has to prepare and fille any environmental impact statements asseciated with the Ssvs installations,these additional measurements may be required for that purpose. Please review this proposal within your organization and withAEAandadviseastohowweshouldproceed. bAehh , Jonn H.YOUaNnS,PLE. Senior Engineer JHD;: Enclosure cc:H.K.Clark -F.S.Prabhakara i.geoet-3]tsteteo es @ .crreer)Meee eee te ttemet cope@Bite apercamess @& emmmi1 a so wend 16:22 ere Pre Power Technologies,Inc.1 AMBIENT MEASUREMENTS SVS SPECIFICATION 10 MEASUREMENT TYPES: Ambicnt measurements for the following items need to be performed so that appropriatevaluesmaybeincludedintheSVSSpecification: Voltage unbalance rarmonic dus voltag -_- Harmonic currents Distartion levels Electrostatic voltage gradient Magnetic ficld strength Radio noise and signal strengths TV noise and signal strengthsieeOeAudiblenoiselevels 10.Power line carrier (if any)noise measurements These should be measured at the proposed SVS installation sitcs.The measurement results should be analyzed and documented properly. 20 RENCRIPTIONOFMEASUREMENTS 21 Voltage Unbalance: The phase-to-phase and phase-to-neutral (if ible)voltages will be measured at113kVbuseso¢at amy other bus where SVS may be connected.The voltageundslancemeasurementatUniversitySubstationwillbeforestablishingareference.Voltage unbalance will be measured at 3 different times,moming,midday and evening. 2.2 Harmonic Bus Voltages: Harmonic content of 115 kV bus voltages shall be measured at UniversitySubstation(reference point),SVS sites #1 and #2,The measurements shall include DRAFT February 2,1990 eos mar-14-90 WED 16s22 PT! Power Technologies,Ine.2 2.3 2.4 2.5 2.6 2.7 DRAFT both characteristic and noncharacteristic harmonics from 2nd through 25th If significant harmonic levels are present,then the harmonic frequency range shall beextendedbeyond2Sthharmonic.Only harmonic magnitude is of interest here.Again the measurements will be repeated at 3 different times during the day to the maximum extent possible. Harmonic Currents; These measurements are similar to voltage measurements.The harmonic currentsinallthelineandtransformersconnectedtothe115kVDusshallbemeasured. Measurements at 3 different times of day will be made to the extent possible. Distortion Levels: These may be measured if there is proper instrumentadon available.Otherwisethesevalueswillbecomputedusingmeasuredquantitiesinitems#2 and #3 above. Electrostatic Voltage Gradicnt: Electrostatic voltage gradient levels at se points along the edge of the propertylineatSVSsites#1 and #2 will be made.These popost-energization measurements can be made at the same location after SVS Magnetic Field Measurements: Magnetic field strength levels will be measured at several points along the propertyline, Radio Noise and Signal Strength Measurements: AM radio ncise and signal strengths will be measured at SVS siics #1 and #2.Asummaryofstationcallsign,frequency,power along with the signal strength willbeprepared.AM radio ficquency noise will be measured at oc near 0.5,1.0 and1.6 MHZ frequency. Measuremenis of radio noise and signal strength will be made using averago,peakandquasi-peak detector settings within the AM and FM bands.Measurements willinctudeatleastthreecompletefrequencyscanningsateachselectedlocation.Themedianvalueofallmeasurementstakenatthatfrequencylocationandmeterscttingwillthenbedeterminedandreportedastheradiointerferencelevelatagivenfrequencyandlocation. February 2.1990 Power Technologies,Inc.3 2.8 29 2.10 Radio naise will be quasi-peak (QP)levels as measured with an instrumentcomplyingwithANSIC63.2-1980 (1 by 160 ms charge and discharge times.9kHzbandwidth).Measurements may be made with instruments heving QP chargeanddischargetimeconstantsof1and600meandabandwidthof5kHz,if thoseinstrumentscomplywithearlierissuesofANSIC63.2.If such instruments areused,the readings should be corrected to a bandwidth of 9 kHz. The measurement will be made at selected points along the property line of thesubstation.A signal to noise ratio (SNR)analysis will be performed. TV Noise and Signal Scength: TV nolse is usually not an tmerference problem,However,some measurements will be made for documentation purposes so that any future complaints can beaddressed.Television signal strength and noise measurements will be inaccordancewithIEEEStandard302overtherangeof30to1000MHzANSIC63.3 standard will define the instruments to be used.The measuring antennashallbeataheightof30feetaboveground. Audible Noise Levels: Audible noise levels will be measured at selected points along the property line ofSVSSites#1 and 2.The measurements will be on A-weighted scale and may berepeated3timesduringagivenday. Power Line Carrier (PLC)Noise: If there are any power line carriers used at proposed SVS sites or University Substation,then the PLC noise measurements in the range of 30KHz to SOOKHz need to be made, Power line carrier noise measurements will be made using commercially available spectrum analyzers euch es HP3S85A.Appropriate bandwidth and impedanceterminationcorrectionswillbemade. 3.0 LOCATIONS The measurement need to be made a three locations: DRAFT University Substation (only harmonics and voltage unbalance) SVS site #1 (all measurements) SVS site #2 (all measurements) February 2,1990 Iid Tes adt Qam @6-er1-avuw mMamr-ia-3a we D 'eH2737285 PFPTre Power Technologies,Inc. 4.0 5.0 SCHEDULE Because of the very tight schedule for specification and SVS procurement,it is imperativethatthesemeasurementsbecompletedassoonaspossible.A preliminary schedule is presented here: 1.Preparation including instrument renting.checkout.calibration and shipping.-2 wecks 2.Measurements at University Substatian,SVS sites #1 and #2 .2 weeks Results and analysis.-3 weeks Total Elapecd Time -7 woeks A total 7 wooks elapsed time will be required.Hence,it is important to schedule thesemeasurementsassoonaspossible. ESTIMATED COST The field measurements,preparation of reports and providing necessary input to the SVSspecificationareestimatedtobe$55,000.This estimate is preliminary and assumes thatallthemeasurementscanbecompletedwithonly1tripby2personteam.Extra timespentduetoweatherandotherflekiconditionsmayincreasetheaboveestimatedcost. DRAFT February 2,1990 ra) ELECTRIC ASSOCIATION.INC. 3 1 MINNESOTA ORIVE «PO.BOX 196300 ¢ANCHORAGE.ALASKA 89519-6300 «SSONE SOARS MILE:'MILE: 907-562-0027 January 30,1990 Power Technologies,Inc. One Sierragate Plaza,Suite 3408 Roseville,CA 95678 Attention:Mr.John Doudna Reference:Bredley Lake Stability StudiesBVSSpecifications Dear John:- I have enclosed a few of the harmonic readings taken from the Bernice Lake Power Plant on Breaker #730 towards Soldotna.We have a multitude of the samples,but I only chased down a couple to give you a rough idea of the problem.The sample enclosedindicatesatotalharmonicdistortioncontentofapproximately 10-15%.Normal readings seem to average around 2-4%,but can reach the higher readings on a frequent basis for prolongedperiods.It should also be noted the readings have a fairly high level of even harmonics.We don't have a reading for the breaker with all of the Bernice Lake units off-line,but I would expect the THD level to increase through 730 as several of the feeders out of the plant can at times exhibit high levels of harnonics. T have also enclosed several snapshots for large feeders out of Bernice Lake wherein the phase relationships are not symmetrical, i.e.3;the angular displacement is 90,150 and 120 degrees betweenphases.This condition rises periodically for various periods oftine.|The longest duration we have measured was approximately 30seconds, As we discussed on the telephone,we have approximately 40 -10MBytediscsofharmonicreadingswhichanyoneiswelcomatouseerreview.The time involved for printing and explaining each ofthereadingsissimplymorethanwecanmanage. tea 'Iba @@2t Lt AG3IM SO6-vF1--AawH maR--14-932 wend amz2zaa Pr:se Power Technologies,Inc. Mr.John Doudna Bradley -SVS Specifications Page 2 I would recommend the specifications be written such that theinformationwehaveisavailableforreview,but design of theSVSfiltersandSVScontrolsbebasedonactualfieldtesting bythesuccessfulbidderwithourreadingsasguidelines. If you would like a few more samples other than what is enclosed,please feel free to call and asx. Sincerely, CHUGACH BLECTRIC ASSOCIATION,INC. Kb oof --avid W,Burl jéganeManager,Facilities Engineering DWB/pv DWB3-46 Enclosures ce:TCS Members File 418 POWER TECHNOLOGIES,INC. FACSIMILE TRANSMISSION One Sierragate Plaza Suite 340B Roseville,CA 95678 Fax #:(916)783-2086 Tel #:(916)783-3566 March 22,1990 TO:Norm Bishop /John Yale Stone &Webster Engineering Total Pages;_1_ FROM:Harrison K.Clark SUBJECT:Proposed Kenai Early Export Analysis PTY/SWEC-051-F Attached please find our proposal (with detailed workscope)for the analysis of Bradley export limits in the early months of operation.To keep the study focusedandthebudgetaslowaspossible,we have made some very definite assumptions,and have outlined the procedure carefully.Under our new working guidelines,theseassumptionsandproceduresaretobereviewedbyAEAandtheRailbeltutilities before we begin work.In this case the assumptions should be reviewed particularlycarefully.This analysis,unlike most others,is not a system planning study --wewillnotbeexperimentingwithsystemdesignchanges,etc.In this study,once the base cases and disturbance files are set up,the only engineering will be to separatethestablecasesfromtheunstablecasesandtabulatethetransferlimits.Hence there will be no opportunity to make changes beyond the first couple of days of setup.On the other hand,because the procedure is largely automated,we will be able to process additional generationfload scenarios or remedial actions fairly economically iftheyarefelttobenecessarybyAEActal. Because the procedure is quite well defined and little engineering is involved,we are able to provide the study within a very modest budget.Additional load/generation scenarios or remedial actions will require additional budget. Also note that we have not included travel and living expenses and time for presentation of results.The work is straight-forward.and the Railbelt utilitiesshouldhavenoproblemdigestingtheresultswithoutapresentation. .?Regards,Harrison Clark fpapp Ct dank 25.Mato Cor¥To Folboy by Ma,SHovlo &e THERE IONOAY, emer eee STUDY PROPOSAL ANALYSIS OF KENAI OPERATING LIMIT WITH BRADLEY BUT NO SERIES COMPENSATION OR STATIC VAR SYSTEMS Purpess The proposed study covers an analysis of the operation of the Kenai system in the early months of Bradley Lake operatian,before proposed series and shunt compensation are available.This study will determine Bradley operating limits for a range of anticipated operating conditions. Procedure This study will utilize Kenai load levels corresponding to winter peak (based on 1988/89 winter models which already exists)and 55%of winter peak (with Tesoro load not scaled).For all conditions,Cooper Lake generation will be scheduled at 16 MW.In addition,the following generation combinations will be examined: 1)1 Bradley Unit with no CTs on-line 2)1 Bradley Unit with Bernice Lake #4 on-line @ 25 MW 8)2 Bradley Units with no CTs on-line 4)2 Bradley Units with Bernice Lake #4 on-line @ 25 MW For the cases with both Bradley units on-line.both units will be equally loaded.This will provide base cases for eight load/generation conditions. For each load/generation condition,an initial operating level will be established with 0 MW Kenai export. Using power flow simulations and starting from the initial operating level for each load/generation condition,the Bradley generation will be increased.The limit for each load/generaticn condition will be set as the Bradley generation level where any Kenai 115 kV bus voltage drops 5% below its level at O MW Kenat export.For these limits,checks will be made to assure that there is a 10 MW steady-state angular stability margin to cover distribution feeder trips.These limits will correspond to maximum emergency operating levels.Such levels will not provide for stable system operation in the event of significant disturbances,but may be used whennecessarytomakeupforgenerationshortagesinthesystemtothenorth. Following the above step,power flow sinmlations will be done to identify voltage and steady-state angular stability limits fallowing line trips and loss of load caused by faulta.Limits for the post-disturbance conditions will be defined as the Bradley generation level at which any Kenai 115 kV bus COTA Ne Ne Ae -=-ae e Power Technologies,Inc.Page 2 voltage falls 5%below its pre-disturbance value.A 10 MW steady-state angular stability margin will aleo be provided. First-swing and dynamic stability limits will be evaluated by starting at the post-disturbance steady-state limits determined above,and decreasing Bradley generation,if necessary,until the system remains first-swing and dynamically stable for faults and associated line trips.An exception to this procedure will be when considering tripping of a Bradley unit.This will allow starting at a higher power level.- Only 5-cycle,three-phase faults which do not island the Kenai will be evaluated.'This will limit consideration of disturbances to those affecting the following lines: Daves Creek-Lawing 115 kV Saldotma-Bernice Lake 115 kV Soldotna-Bradliey Lake 115 kV Soldotna-Diarnond Ridge 115 kV Soldotna-Quartz Creek 115 kV Automatic,high-speed reclosing into a permanent three-phase fault will be simulated for faults on the Daves Creek-Lawing line and the Soldotna-Quartz Creek 115 kV line.'Information gained from prior work and trial and error cases will be used to select the single worst-case disturbance for each load/generation condition. The following stability aids will be examined: 1)No remedial action 2)Application of 50 MW of braking resistor at Bradley 3)Tripping of one Bradley unit 4)A combinationof1 and2above Unit tripping will have the double advantage of improving first-swing a Dieturbancese which ieland the Kenai have been covered in cther 2ooent work.The combination of braking resiatora and Bradley deflector run- in have been shown to he quite effective at keeping Kenai frequency under 61 Hz following separation under all but the very highest export levels. However,there may be a question as to whether the deflector run-in capability will exist in the Sradley governor when the early months of operation.If deflector run-in capability is not available,unit tripping may be used,butmaynotmeetthe$8.5 and 61.5 He and load shedding (avoidance of)criteria. ?Reaclosing practices for Kenai area transmission lines were reviewed with Dave Burlingame of CZA and Sam Matthews of HEA.Automatic, high-speed reclosing is only used or contemplated on tnese two lines. Power Technologies,Inc.Page 3 stability and reducing post-fault transfers to remain within acceptable limits.Though system planning studies have not considered unit tripping. it may be attractive in the early months of Bradley operation under some operating conditions. Bradley generation levels under each of the 8 load/generation conditions will be determined for each of the above four stability aids or combinauions of stability aids.A total of 32 export levels will thus be defined in this study.Conditions between 55%load and 100%load can be determined by interpolation. The following additional assumptions will be made: ¢Bradley deflector rin-in to quickly reduce Bradley power folldwingfaultsorlinetripswillnotbeavailablefortheperiodofoperationthis study addresses. °Bradley stabilizers will be in operation under all conditions addressed in this study. ¢30 MVAR of switched shunt capacitors will be available at Soldotna hadandwillbeequippedwithovervoltagerelaystosequentiallyremove(_¢*"-banks when 115 kV voltage exceeds 110%of nominal.*Some or all g(f hofthecapacitorswillbeon-line under initial conditions to support vd feSoldotna115kVvoltage.No additional capacitors will be switched petonduringorfollowingdisturbances,'yhnn]yy Report The results will be presented in a brief report.Steady state (emergency) stability limits to Bradley generation will be tabulated.Only selected stability plots will be included tn the report.A draft report will be preparedforcommendandafinalreportwillbeprepared. 3 Somm conditions such ae trip of a axadley unit to maintain stability may resulta in a drop in power flow through the Soidotna bus and an increase in Soldotna voltage. 'Operators may apply off-line capacitors following disturbances.but for the purposes of this study voltage criteria will be applied before operators apply the capacitors. Power Technologies,Inc.Page 4 Cost Estimate |The study is estimated to require the following engineering time: Set up hase case power flows 2 days Run approximately 150 stability cases 4.5 days Prepare draft report 1 day Prepare final report 0.5 day Computer charges 40 hours @ $13/hour $520 The engineering will be conducted by a Senior Engineer at $020 per day(long-term rate).Total engineering charges are thus estimated at $7,360. Total of estimated engineering and computer charges is $7,880. The above estimate does not include time for report presentation or associated travel and living expenses.The estimate also does not include an allowance for study of additional operating conditions that Ratlbelt engineers may determine to be useful. John Doudna Harrison Clark March 22,1990 SAAT Asie omen TELECOPY TRANSMITTAL FORM AX stone &WEBSTER ENGINEERING CORPORATIONDENVEROPERATIONSCENTER GREENWOOD PLAZA,DENVER,COLORADO TELECOPY OPERATOR:(303)741-7234 3M HIGH SPEED TELECOPY NUMBERS:(303)741-7870 and (303)741-7671 to:__Lduwe,Eberle __.Location:AEAFROM:yi.Val a DOC LOCATION-QUAD 4427 SPECIAL NOTE TO RECEIVING TELECOPY OPERATOR JOB OR ACCOUNT NUMBER 1580.55 pate:le hteNEARESTTELECOPYPHONENUMBER-207-40/-£5 2Y TYPE OF RECEIVING TELECOPY MACHINE VERIFICATION NUMBER SPECIAL NOTES TO DOC TELECOPY OPERATOR: (ALL OF THE ABOVE MUST B&FILLED IN BY SUBMITTER:USE RALL POINT PEN) NAME OF OPERATOR SENDING MESSAGE: NOTES: sp Roce?A TOA WAAAY?Awe OD emt Al LO se STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREETAENGLEWOOD,COLORADO 80111 ADDRESS ALL CORRESPONDENCE TOPO BOX 5406,DENVER,COLORADO 80217 5406 wu Twx 910 935-0105 TELEPHONE 303 741.7700 FAX.33-741-7670 WU TELEX 45-4401 RCA TELEX 289251 3O3-741.767! enatraNOOGA coetiano we CERRY iLL NS FORaTLANO Of cmcaco QCmLand wa Oauas MiCMMOND va DEnver Sam Faanci8sco er LAUOEROALE Tamra *OUSTON WASMINGTON OC Mr.Harrison Clark March 26,1990 POWER TECHNOLOGIES,INC. One Sierragate Plaza J.0.No.19239.21 Suite 340B -_WP 26A Roseville,CA 95678 SWEC/PTI/017 REQUEST FOR QUOTATION FOR ADDITIONAL STUDIES P.0.NO.EPR-CS-190-62-03672 BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY It is likely that the transmission system compensation and brake resistors will not be operational until after the units are available for generation.The Alaska Energy Authority and railbelt utilities would like to know to what level they may operate Bradley Lake under the following conditions: 1.Bradley Lake units without any stability compensation;with unit tripping;the third governor mode and deflector control;and without any combustion turbines operating on the Kenai Peninsula. 2.Same as 1 except with combustion turbines operating on the Kenai Peninsula. 3.Bradley Lake with the brake resistors third governor mode and deflector control,without combustion turbines operating on the Kenai Peninsula. 4.Same as 3 except with combustion turbines operating on the Kenai Peninsula. Please provide a not-to-exceed estimate and a proposed schedule to determine the one-and two-unit operational limits for the conditions described above.A report (10 copies of draft and 30 copies of the final) should be included in your estimate.All other items and conditions of the contract remain the same. Slidlisw AW.HatathleenH.Wood Manager -Procurement KHW/JBY/CM ec:D.R.Eberle/AEA . itte +STONE &WEBSTER - ( STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREETAENGLEWOOD,COLORADO 80111 ADORESS ALL CORRESPONDENCE TO PO 8OX 5406,DENVER,COLORADO 80217 5406 WU TWX 910 935-0105 TELEPHONE 303 741-7700 FAX.303.741.7670W.U TELEX.45-4401 RCA TELEX 289251 303-741.7671 Boston NEW YORKCHarranooGcaPORTLAND mE CHERRY MILL ND PORTLAND Of cmcaca RICHLAND wa OALLAS RICHMOND VA Fr AUDEROALE e Famen NSISESmOuUsSTONWASHINGTONOC Mr.D.R.Eberle September 19,1990 Project Manager Alaska Energy Authority J.O.No.19239.21 701 East Tudor Rd.WP 26A Anchorage,AK 99503 SWEC/AEA/2618 SYSTEM STABILITY BRAKE SOLUTIONS BRADLEY LAKE HYDROELECTRIC PROJECT Power Technologies,Inc.(PTI)has run and analyzed 20 case studies to demonstrate system performance with two SVS and no series capacitors.Case plots and the PTI analysis was sent under separate cover on August 24, 1990.Stone &Webster has reviewed and analyzed these case studies and concurs with the PTI recommendation that a braking resistor is not a cost effective device to aid in maintaining stability or lowering frequency after islanding. Two problems have been identified by previous studies,overfrequency due to islanding and system instability caused by specific perturbations.Braking resistors were a part of the solutions to these problems.Relaxing of assumptions relating to allowable transient system parameters and better modeling techniques have shown that the braking resistor is no longer required. Study results for islanding have been effected to the greatest extent by the increase in allowable overfrequency to 63 h.and by a _better representation of the deflector versus needle characteristic.The first set of plots prepared by PTI show that with a 75 MW export an overfrequency of 62.6 hy,results for a fault at Davis Creek and loss after 5 cycles of the University -Davis Creek 115 kV line.With additional generation in the Kenai but with Bradley Lake at 90 MW the overfrequency is about 62.0 h,for the same three phase fault as indicated on the second set of plots. The next 18 sets of plots demonstrate system performance with respect to transient stability.The case studies represented by the plots indicate the system to be transient stable for loadings of Bradley Lake to about 100 MW without the use of a load bank resistor.Loadings above 100 MW are generally unstable without a resistor but would require additional remedial itty STONE &WEBSTER =: Mr.D.R.Eberle September 19,1990 Page 2 action if a resistor was used.Additional action could include stabilizers on SVSs,larger SVSs,deflector runbacks or generator unit tripping. Generator unit tripping as a sole remedial action will maintain the system within operating limits for transient,dynamic and steady state conditions when Bradley Lake is at its rated output of 120 MW without the resistor and is the least cost option available to solve the stability problem. Bradley Lake has a limited ability to operate at 120 MW because of water storage.It is likely that its use at this level will be at high load times and that there is only a few hours each year that the conditions identified in the PTI study will exist.Secondly,there is a very high Marginal loss under these conditions.It is estimated that approximately 15 MW of losses exist for a 120 MW output at Bradley Lake with the 75 MW export.A unit trip of 60 MW would reduce losses to approximately 5 MW, thus the effective loss is only 50 MW to serve load. Stone &Webster recommends against the installation of a braking resistorbasedonitslimiteduse,high cost complicated controls and _therequirementtoreducegenerationinmostcasestomaintaindynamicand steady state system limits after a disturbance.The addition of a brake adds very little value to the system for a relatively high cost. N.A¥Z Bishop Deputy Project Manager NAB/CM ccs:TCS Members CHUGACH ELECTRIC ASSOCIATION,INC. a Anchorage,Alaska \ September 20,1990 . TO:Bradley Lake Project Management Committee FROM:David W.Burlingame,Bradley TCS Representative fo SUBJECT:Technical Coordinating Subcommittee (TCS)Report The following is a brief synopsis of the 2 TCS meetings held since the last meeting of the Project Management Committee (PMC): Ju 9 90 Meeti Stability Studies -It was agreed that any stability studies required to ensure the proper incorporation of Bradley Lake into the Railbelt system would be included as part of the project. The committee adopted a list of stability cases intended to assess the interim operating limits of Bradley Lake.The interim period is the period between the time Bradley Lake becomes operational and the time when stability aids such as SVS installations are installed on the systen. SCADA -A listing of points to be connected to the Chugach RTU was distributed and approved. Soldotna -Bradley Lake Line -Homer Electric Association,Inc. (HEA)stated the line is scheduled to be completed by April 1, 1991. Unit Tripping -The committee agreed to allow tripping of one or both of the Bradley Lake units if tripping of these units would allow a higher operating capacity for the plant and improve thestabilityandpostfaultconditions. Series Capacitors -Stone &Webster Engineering Corporation (SWEC)recommended against the use of series capacitors in the Kenai 115 kV system.The recommendation was made due to the concern for subsynchronous resonance on the Kenai.The recommendation was unanimously adopted. Braking Resistor -SWEC stated they would not endorse the use of the braking resistor used in the manner proposed by PowerTechnologies,Inc.(PTI).SWEC believes the scheme is too complicated and may never work as intended.SWEC also expressedtheirconcernovertheuseofbrakingresistorsingeneralbasedon their discussions with personnel at the two installations in North Anerica. Bradley Lake Project Management Committee TCS Report September 20,1990 Page 2 Stability Criteria -HEA and Chugach agreed to allow the transientoverfrequencytoriseabove61.5 Hz,if no detrimental effects to turbines or consumers was encountered. Generator Stabilizer -SWEC recommended the purchase of a Fuji power system stabilizer as opposed to the previously specifiedGeneralElectric(GE)or PTI digital stabilizer.The Fuji stabilizer is analog and does not have the control characteristics used in the stability studies but is considerably cheaper than either digital stabilizer.The Committee accepted the recommendation provided the use of the Fuji stabilizer does not result in any decrease in the capacity output of Bradley Lake. August 30 90 Meetin Generator Test Reports -The committee generally agreed the test reports performed by PTI were done very well.The tests brought up several questions in regards to the performance of some units in the system.SWEC was directed to put the Kenai generation test reports in the same format. Bradley Lake Procurement and Testing Schedule -The schedules for the start-up and commissioning of the Bradley Lake units and the subsequent installation of the SVS systems was reviewed. Basically,the start-up of Unit #2 will commence in May with on-line testing starting sometime in June.The unit is scheduled to be turned over to the utilities for operation July 1,1991 and scheduled to go commercial September 1,1991.Unit #1 will follow approximately 30 days behind Unit 2's schedule for testing andutilityoperationwithcommercialoperationalsoscheduledfor September 1,1991. The installation of the SVS systems is optimistically scheduled for June 1992,with utility acceptance in January,1993. Braking Resistor -SWEC recommended against the installation of a braking resistor at Bradley Lake.The recommendation was based on the use of unit tripping and frequency excursions up to 63 Hzfollowingislanding.The recommendation was adopted by thecommitteependingthereviewoftherequiredstabilitycasestoshowdeletionofthebrakewillnotresultinanycapacityreductionsforBradleyLake.It was felt unit tripping for theBradley-Soldotna Line and the frequency excursions to 63 Hz will allow Bradley to operate at 90 MW in the fall of 1991. Bradley Lake Project Management Committee TCS Report September 20,1990 Page 3 The TCS recommended including the costs of dual porting the HEA Diamond Ridge RTU as part of the project cost.Dual porting will eliminate a CPU-CPU link which would have been required between the Chugach and HEA SCADA systems.The cost of the dual porting has been quoted by HEA's RTU vendor as $30,974.00.The recommendation will require PMC approval. The PMC also needs to approve the reimbursement to Chugach of $95,441.09 for relay additions required at HEA's Soldotna Substation for the operation of Bradley Lake.The expenditure was approved by the TCS in December,1988 and was thought to have been approved by PMC but no resolution has been found in the records.The original Technical Coordinating Committee (TCC)resolution was for the installation of subject relays was not to exceed $115,000. Since the TCS meetings,HEA has indicated there may be some problemwithfrequencyexcursionspreviouslyadoptedbytheTcs. -DWB/pn DWB4-65 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska November 1,1990 TO:TCS Committee Members FROM:David Burlingame,Chugach Electric Association SUBJECT:Bradley Lake TCS Meeting of October 25,1990 The following are the minutes of the above referenced meeting, reviewed corrected and approved at the November 16,1990 meeting. The SVS specification has been submitted to three vendors for review and comment,GEC,ABB and Siemens.The specification is currently scheduled to be released for technical response by December 31,1990.SWEC has received comments from Chugach and GVEA.MEA and HEA indicated they would have no comments on the specifications.ML&P will comment,if any,within one week. The utilities requested SWEC confirm the specification will not allow the SVS systems to oscillate with the system in any way and insure the losses for the building heaters etc are included in the loss calculations and evaluations. SWEC expressed concern over the apparent loss calculations supplied by Chugach as being too low.Chugach and SWEC will discuss this evaluation.It was discussed as to whether or not an average KWH figure for all of the railbelt utilities should be used as opposed to the Chugach numbers,but it was agreed that SWEC would use the Chugach numbers as a base and adjust them if they felt it would result in too lossy of a systen. The TCS approved a motion for PTI to analyze the data Chugach has been collecting on system harmonics.Based on their analysis,PTIwillrecommendeitherdesigningtheSVSsystemstooperateunder these conditions or will attempt to find the source of these harmonics.The motion read as follows: -Recommend PTI to analyze the Chugach data to determine what harmonics are present and make a recommendation as to what further action is required. Braking Resistor -The TCS formally approved by motion SWEC's recommendation to delete further consideration of the use of braking resistors at Bradley Lake.The motion was based on three factors: -The worst case frequency excursion is with Bradleyoperatingat120MWwithonlyCooperLakeonlineintheKenaiat 16 MW and loss of the University Daves Creek 115 kV transmission line.The frequency rises to 62.6 Hz before settling out to 60.8Hzapproximately5secondslater.The frequency is above 61.5 Hz reconstructed 69 kV line providing little support for the system. -In all cases the two SVS system allows higher export and stability levels for the Kenai. AEA directed SWEC to determine the size of the northern SVS with consideration of 100 MW of Kenai export and the second Kenai intertie.AEA directed SWEC to perform the studies as previously agreed on by the TCS.SWEC will run the required studies to determine the size of the SVS based on different generation scenarios. The TCS was given a verbal presentation of the interim operating limits.The interim limits for operation of Bradley Lake prior to the installation of the SVS systems appears to be fairly limited. Basically,without a gas turbine on the Kenai,there can be no more than 16 MW of export from the Kenai in the summer,or 2 MW of export in the winter or more than 18 MW import in the winter and -5 MW import in the summer.The following table gives a brief description of the restrictions which will be present during thefirst18monthsofoperation. Stable Operating Limits Load Condition Generation export/import Peak CLPP 16 MW Bernice 0 Bradley 65 2 MW Peak CLPP 0 Bernice 0 Brad 60 -18 Peak CLPP 16 Bernice 23 Bradley 80 25 Off-Peak CLPP 0 Bernice 0 Bradley 50 -5 Off-Peak CLPP 16 Bernice 0 Bradley 55 16 Off-Peak CLPP 16 Bernice 29 Bradley 80 70 Notes:1.import/export is measured at Daves Creek station flowing to/from University 2.These export levels require a slight modification totherelaying/controls at Quartz Creek or the opening of the 69 kVlinebetweenSoldotnaandQuartzCreekforflowsabove35MW. The TCS recommended including $12,000 for PTI to convert the machine tests done for the Kenai into the same format as the railbelt test report. Start-up and Testing is now expected to be delayed 30 days fromoriginallyexpected.This will cut down on the time the utilitiesareallowedtooperatetheunitspriortobeingdeclared commercial.The delay has not been finalized yet,but is anticipated by SWEC. The TCS recommended a Dynamic System Monitor be installed at Bradley Lake and the units be tested to determine the parameters ofthemachines,similar to the tests done on the railbelt generators. PTI distributed a revised test report for the ML&P unit 5 generator.The revised tests indicate the machine droop is 3.4%asopposedto-.0088%as depicted previously. File 411 ( STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREET RECEIVED ENGLEWOOD,COLORADO 80111 -1914 DotanAADORESSALLCORRESPONDENCETOP.O.BOX 5406,DENVER,COLORADO 80217-5406 ow WU Tec anor REATELE evs FAN Oe yal er Tes feet sy eae enarraMoOen soprano we Catia gan Paancisco vouenen ee TeariNGTON oc Mr.D.R.Eberle October 22,1990 Project Manager Alaska Energy Authority J.O.No.19239.26 701 East Tudor Rd.WP 26A Anchorage,AK 99503 RECOHD E7670FILENOPOWERSYSTEMSTABILIZER BRADLEY LAKE HYDROELECTRIC PROJECT . Prd a4.(te: Power Technologies,Inc.(PTI)hag analyzed the electric system performance Ywithapowerinputstabilizer(the Fuji stabilizer)and an accelerating power stabilizer (the PTI stabilizer)on the Bradley Lake units.The PTI analysis is documented in the report Bradley Lake Stabilizer Options,dated October 15,1990 (PTI/SWEC 091-L).Stone &Webster Engineering Corporation (SWEC)has reviewed the PTI work. Accelerating power is determined by taking the difference from the mechanical power and the electric power.When mechanical power does not change during a transient,both stabilizers will provide near equal performance.During islanding the turbine governor is rapidly trying to reduce mechanical power.In this case the accelerating power input stabilizer (PTI's)can recognize the unbalance of mechanical power and lower the field and thus lower generator voltage much faster.This Maintains a better voltage profile than that which can be achieved by the power input stabilizer (Fuji's). The better voltage profile during this transient condition results in a reduction in the size of the SVS requirement of about 15 MVAR.This savings is estimated to be approximately the same as the difference in the installed cost between the electrical input power and accelerating input power stabilizer. Since the total system cost are about equal,including installation costs, better performance is expected and operation and maintenance cost should be lower for PTI's stabilizer.We recommend that PTI's accelerating input power stabilizer be purchased for the Bradley Lake Units...-----= A ORDENCE DISTT A 2 3 LO ACTION:corits:| 6,SRE Theodore Critikos Project Manager TC/MWG/CM ec:HClark (PTI)1 OS F OWE EESTER oe Fle oO r) ELECTRIC ASSOCIATION.INC. 5601 MIt.*.=SOTA OR .=¢PO BOX 196300 «ANCHORAGE ALASKS 225°9 632°¢P4ONE 907 563 749: 'FACSIMILE. 907-562-0027 TELECOPY TRANSMITTAL SHEET TO: JOHN DOUDNA COMPANY:POWER TECHNOLOGIES,INC. LOCATION:ROSEVILLE,CA TELECOPIER NO.:(916 )783-2086 FROM:DAVID BURLINGAME SUBJECT: Draft Meeting Minutes -April 3,1991 TCS Meeting COMMENTS: Le TOTAL NUMBER OF PAGES TRANSMITTING/d (Inclides Cover Sheet) IF TRANSMISSION IS INCOMPLETE,PLEASE CALL:(907)7624633 \ TIME/DATE OF TRANSMISSION:BY:ALAN OR\JC CHUGACH TELECOPIER NO.:(907)562-0027 MACHINE TYPE:CANON 705 OR CANON 850 ---DRAFT DRAFT DRAFT-- - CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska April 3,1991 TO:TCS Members FROM:David Burlingame,Secretary SUBJECT:Draft Meeting Minutes -April 3,1991 TCS Meeting Previous Meeting Minutes were approved with one modification to state the Motion on SVS size was passed unaminously. SVS Specification -Three addendums have been issued to the technical proposal specification,the first addendum was grey and included the material prepared by PTI and some clarification comments on specifications,the second was blue and addressed commercial concerns and extended the bid date,the third was green and addressed responses to questions asked by the prospective bidders Bids for technical responsiveness are due April 16,1991.Target date for receiving price quotations is the first part of June 1991. Interim Operating Study -The interim operating study was discussed and several comments and suggestions were requested to beincorporatedintothereport.Some of these were to address a non- reclose situation as something other than a failed reclose attempt,address the Bernice-Soldotna 69 kV line benefits of running closedfromasystempointofviewasopposedtosimplyaBradleypointofview,explain the recommendation to delay reclosing on the DavesCreek-Lawing 115 kv line,and that reclosing is not employed atQuartzCreek.SWEC was also asked to either run a case or explainpossibledifferencesbetweenrunningallthreeBerniceLake turbines versus only one turbine at the same output.As all of thecommentsareminoranddonotchangetheresultsofthereport,SWEC will finalize and distribute. Based on recommendations included within the report,the followingmotionswereadopted: MOTION -Move to install transfer tripping on the Bernice Lake -Soldotna 69 kv line as part of the Bradley Lake project.MotionpassedwithML&P and AEA voting no. MOTION -Move to install transfer tripping on the Soldotna -QuartzCreek69kVlineaspartoftheBradleyLakeproject.MotionpassedwithAEAvotingno. MOTION =Move that the PMC authorize installation of transfer feipping on the above referenced circuits at a cost presentlyfpostimatednottoexceed$75,000. pen ee«ting MOTION -Move that the PMC authorize Chugach to install transferioetrippingofitscapacitorbankfromDavesCreekatacostnottoexceed$30,000.Transfer tripping of the capacitors will enable ahigheroutputofBradleyLakeduringtheinterimoperatingperiod. PSEE/PTI program purchase -AEA needs a written commitment ASAP as to how many copies of the program will be purchased. DECNET -The IOC has decided to have ML&P and GVEA as 'the DECNET nodes. Start-Up and Testing Subcommittee -GVEA has requested to be notified of all meetings and wishes to be included in the committee from this date on.Chugach will island the Kenai .sometime aroundthethirdweekofJune.SWEC needs-'to determine how this'effectsBradleytestingtoallowChugachtoevaluatethecost/benefit of a shoefly around the construction site. PTI will determine what generation configuration will be required for Bradley Lake testing. Schedule is still basically the same as handed out at the last TCS meeting with the exception that tunnel watering could be earlier. Kenai Import/Islanded Study -After considerable debate it was agreed the Committee would have PTI define the level of historical loadshedding experienced on the Kenai and attempt to compare thattowhatcouldbeexpectedwithBradleyLake.To this end,PTI will perform eight cases of historical generation scenarios with specified import limits.These cases will be run with the existingloadsheddingsysteminservicetosimulatehistoricalevents,the case will also be run without loadshedding in service.PTI willthenrunfivecaseswithspecifiedimportandgenerationlevelsandtheexistingloadsheddingsysteminservice.The cases will be repeated without loadshedding in service. The results of these cases will be forwarded to the Committee for evaluation.Based on these cases the Committee will determine the acceptable level of loadshedding the Kenai should be expected toencounterbasedonanysinglecontingency. The issue of operating the system in an islanded mode will be addressed after the cases are received. Synchronous Condenser Operation -SWEC stated they are at the pointwheretheabilitytooperatetheBradleyLakeunitsassynchronouscondensersneedstobemade,the change will at this time costslessthen$15,000. The following motion was passed unaminously: pot cor ON -Move to install synchronous condensor modes of operation»for the Bradley Lake units.; sso Studies -SWEC indicated they are in need of generatorinformationfortheSoldotnaunittodeterminetheSSOpossibility. HEA indicated they had already forwarded the information to PTI. SWEC will contact HEA if it can not be located. cc:TCS Members APPENDIX Kenai Import Study Cases Chugach has researched their Dispatch records for 1990/91 andproposethefollowingcasestoberunaspartofthePTI loadshedding study relative to Bradley Lake. We were not able to fully match the PTI letter,simply because some of the Dispatch cases did not occur. The cases are as follows: Summer 1990 -In July,August and September 1990,there were lessthan10dayswhentheKenaihadlessthantwogasturbineson-line,the only time Cooper Lake was on-line was when all three gasturbinesatBerniceLakewereoperating,the Kenai was islanded forthemajorityofthetimeduringthisperiod.This may beconsideredtypicalforthenexttenyearsduringthe115kVlinereconstruction. The following scenarios are proposed based on the research of actual 1990 summer Dispatch scenarios: Summer CASE I Univ 730 load 31.5 BLPP #3 6.4 BLPP #4 22.2 aCASE II Univ 730 Load 0 MW (intertie opened between Hope andPortage) BLPP #2 4 BLPP #3 14 BLPP #4 21 CLPP #1 8 CLPP #2 8 BSna5CASE III Univ 730 load 28.0 BLPP #3 7.4 23 opupp #4 ™". Winter -The vast majority of dispatch scenarios examined fromOctober1990January1991hadtwogasturbinesandCooperLake on-line,there were a fair amount of cases with one gas turbine and Cooper,there were no cases of only a gas turbine without Cooperunits.The following cases are proposed for the typical winter dispatch scenarios: CASE I Univ 730 load 41.0 MW BLPP #3 12.3 MW BLPP #4 12.6 MW CLPP #1 8.4 MW CLPP #2 8.4 MW CASE II Univ 730 load 46.4 MW BLPP #3 19.0 MW CLPP #1 8.0 MW CLPP #2 8.0 MW Peak Case -During the 1989 system peak,BLPP #2 was cycled on/off based on spin requirements,the following case is proposed for the system peak case. Univ 730 load 43.5 MW BLPP #2 3.4 MW BLPP #3 16.8 MW BLPP #4 7.2 MW CLPP #1 8.1 MW CLPP #2 7.9 MW Sold #1 5.9 MW Spring Cases -During the Spring of 1991,the majority of casesinvolvedonegasturbinebothwithandwithoutCooperLakeon-line, followed by several days of two gas turbine operation.There were no times when three turbines were on-line for any significantperiodoftime.It should be noted that during any time when thereisonlyonegasturbineon-line without Cooper Lake,the City ofSewardisautomaticallyshedforanyuncommandedopeningofDavesCreekBreaker826. The following cases are proposed for the loadshedding study: CASE I Univ 730 load 36.4 MW BLPP #4 20.1 MW CLPP #1 7.2 MW €ASE III 'Univ 730 a.»49._BLRP #3 4. "Sold #1 6. pue to the extreme variation in Dispatch scenarios found during the me9MW 6 MW O MW research,it has become even more obvious that-there is not a "typical"scenario for the Kenai.These cases are considered tobetypicalforthemonthsinwhichthestudyisintendedto -simulate. Please advise if these are acceptable prior to them being forwardedtoPTI.Your earliest response is appreciated. emael ah ts CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska April 11,1991 TO:Brad Evans,Manager,Power Control FROM:David W.Burlingame,Manager,Facilities pasnecring DUC F- SUBJECT:Underfrequency Relay settings The following loadshedding schedule is to be effective April 11,1991.This superscededanypreviousloadsheddingschedules. System Stage 1 .89 Peak Load Woodland Park 59.2 Hz 8 cycles 9.9 MW Sand Lake Trf 1 59.2 Hz 8 cycles 8.0 MW O'Malley 59.2 Hz 8 cycles 9.3 MW Campbell Lake 59.2 Hz 8 cycles 7.6 MW Raspberry 59.2 Hz 8 cycles 7.4 MW TOTAL 42.2 MW Svstem Stage 2 89 Peak Load Jewel Lake 58.8 Hz 8 cycles 9.0 MW DeBarr 58.8 Hz 8 cycles 20.2 MW Sandlake Trf 2 38.8 Hz 8 cycles 10.5 MW--Aretie-w/o-F12--__--58.§-Hz-______8-cyeles14.0 MW.00 Bl relays TOTAL 53.7 MW System Stage 3 89 Peak Load Turnagain 58.5 Hz 8 cycles 8.5 MW Boniface 58.5 Hz 8 cycles 14.6 MW Spenard 58.5 Hz 8 cycles 9.8 MW Tudor 58.5 Hz 8 cycles 4.7 MW Airport -/5 3:2 58.5 Hz 8 cycles 8.0 MW TOTAL 45.6 MW The total amount of load on the undertrequency loadshedding program is 141.5 MW basedonthe1989peakreadings. The backup underfrequency settings,labeled as Stage II for each substation on SCADA,areasfollows: System Backup for Stage 1 Woodland Park 59.3 Hz 40 cyclesSandLakeTrf159.3 Hz 45 cyclesO'Malley 59.3 Hz 50 cyclesCampbellLake59.3 Hz 55 cyclesRaspberry59.3 Hz 60 cycles System Backup for Stage 2 Jewel Lake 59.0 Hz 25 cyclesDeBarr59.0 Hz 35 cyclesSandlakeTrf259.0 Hz 40 cyclesArcticw/o 712 59.0 Hz 50 cycles System Backup for Stage 3 Turnagain 38.8 Hz 20 cyclesBoniface58.8 Hz 30 cyclesSpenard38.8 Hz 35 cyclesTudor38.8 Hz 40 cyclesAirport58.8 Hz 60 cycles It should be noted that following the last stage of underfrequency loadshedding,five of theeight34.5 kV feeders will be completely unloaded.SCADA installation at Dowling andKlattsubstationsthissummerwillunloadallofthe34.5 kV feeders except University 1230(Huffman)following a Stage 3 shed. cc:M.Massin D.Rogers File 1060 J.Loel. STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUE Foe AseAENGLEWOOD,COLORADO 80111 -2137 ADORESS ALL CORRESPONDENCE TO P.O.BOX 5406,DENVER,COLORADO 80217-5406 WU.TWX:910 935-0105 TELEPHONE:303 741-7700 FAX:303-741-7670 W.U.TELEX:45-4401 RCA TELEX:28925)W3-7 41-7671 ew vonn wv NOV 21 1991 Mr.D.R.Eberle DIRECTOR November 20,1991 Project Manager ENGINEERING DIVISION Alaska Energy Authority J.O.No.19239.26 701 East Tudor Rd.WP 26A Anchorage,AK 99503 SWEC/AEA/2793 INTERIM OPERATING STUDY BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY Power Technologies,Inc.(PT!)has completed the additional studies requested at the October 31,1991 Technical Coordination Subcommittee (TCS)meeting.Stone &Webster Engineering Corporation (SWEC)has reviewed the PTI study effort described in the attached report "Interim Operating Study for the Bradley Lake Hydroelectric Project,Addendum 1 to Supplement 1.SWEC concurs with the PTI recommendations and believes the recommendation should be incorporated into the interim operation guidelines for the Bradley Lake Units. Unit tripping,a refined utilization of the Soldotna Capacitors and the use of absolute voltage limits are the difference from the conditions used for cases A,B,D,and E of the original Interim Operating Study dated March 19,1991.SWEC will incorporate these study results into the Dispatch Operations Summary. Se orlone Grtehbe Theodore Critikos Project Manager Enclosures cc:TCS Members J.Doudna (PTI) TC/MWG/swg 000591..wpt/BLO03 maty >STONE &WEBSTER: SPEFED REFERENCE 'TROL (tpDu (techfostuom Crop FraquinAowtrold©Rois2<nRa|ronce/Lower {902 ett See Sum 0 nic clos F Absoluls Vlas ee)-_--eneem <1% 4 FASE, |t/FACE {A vous <oanTRUE/EAL q rat 20.S¥/a4«<asavalueIN202 bit/se So rab 23%/sac a Post tion teste ; ' ' 4 -=«7a Ke 4/0CHUGACHELECTRIC ASSOCIATION,INC.jgech ASSOCIATION.INC August 8,1991 Municipal Light &Power 1200 East ist Avenue Anchorage,AK 99501 Attention:Mr.Moe Aslam Reference:Bradley Lake Testing Your Letter of August 1,1991 Dear Moe: In your letter to Dave Eberle of the Alaska Energy Authority (AEA),it is inferred the system modelled by Power Technologies, Incorporated (PTI)may be fairly similar to the actual system response.The actual system response as measured at our Plant #2 and Bernice Lake recorders and even the ML&P freeze data is considerably different than what has been modelled and expected by PTI. You are correct in that the trip of July 20,1991,was not a true unit trip but rather a deflector cut-in after an over-temperature alarm.This shut-down method was intentionally installed by Stone &Webster Engineering Corporation (SWEC)to provide for a ramp down of Bradley Lake power and to keep the inertia of the Bradley Lake units connected to the system to reduce the rate of frequency decay.This control mode appears to actually increase the frequency decay rate due to the inertia transfers between the Kenai and Anchorage systems.The system response of this Bradley control system shutdown was opposite the response SWEC or PTI predicted for the system. The PTI study you reference for the generator tests concluded there is no significant difference between different machines within the system supplying the required spin in terms of frequency recovery,therefore according to PTI,the fact that unit #8 was not on-line but it's spin was displaced by separateunitsshouldnothaveeffectedthefrequencyresponseofthe system.In attempting to recreate this case,PTI has apparentlyfoundtheactualgovernorresponseontheBernice,ML&P and Beluga units to be considerably less than predicted by PTI.Thestudiesarebeingtunedtomoreaccuratelypredictactualsystem responses. 5601 Minnesota Drive ¢P.O.Box 196300 «Anchorage.Alaska 99519-6300Phone907-542-7404@FAX ON7.5A9.NND7 Municipal Light &Power Mr.Moe Aslan Bradley Lake Testing August 8,1991 Page 2 An example of the differences may be the 3%droop for ML&P #7quotedinyourletteror4%as calculated by PTI for the sameeventversusthe2.2%droop in the system model,or the actualloadreductionofunit#7 which was not predicted by the PTI study.The point being the model is different than the actual systen. The large swings recorded on the Bernice Lake DSM are the result of inertia interchange between the units.If you examine the time constant of the swings you will note the period is considerably faster than any machine response to system conditions.These swings were initially predicted by PTI, however not to the degree measured. Frequency was still decaying fairly rapidly at 200 cycles from the time of the event so we are unsure as to what other recordings you have to indicate otherwise.The frequency decay did not bottom out until 245 cycles into the event.This point is after Chugach Electric Association,Inc.(Chugach)and GoldenValleyElectricAssociation,Inc.(GVEA)shed load.To imply theloadsheddingcouldhavebeenavoidedisconjectureandshouldnot be presented as factual. The appropriateness of any utilities unit response and as to whether it is "rapid"or not is not the issue,nor should it come under the TCS.It is presumed the appropriateness of anymachines'response would come under the Machines RatingSubcommitteetotheIoC.The issue related to Bradley Lake andtheTCSisthemachinesrespondedconsiderablydifferentthanthemodelPTIisusingtobasethestabilitysolutionson. It is our understanding PTI has since determined the inertia response required from the system and the inertia transfers over the single 115 kv intertie create a situation worse than originally predicted by PTI for unit trip situations,similar totheinertiatransfersbetweenAnchorageandFairbanksnotedintheoriginalreport. In suggesting the restrictions on Bradley Lake be lifted,yourletteromitstheout-of-step condition experienced with ourBerniceLakemachines.These generators were subjected to powerswingsfrom+45 MW to -25 MW on each unit and correspondingvoltageswingsin50cycleperiodsfor10secondspriorto Municipal Light &Power Mr.Moe Aslam Bradley Lake Testing August 8,1991 Page 3 Bradley being tripped off-line.Bernice Lake unit #4 has been retested by PTI after this event to insure the machine is still behaving as tested in 1989,yet PTI has not been able to reproduce this unstable condition in simulations. Until a credible response to both the underfrequency condition and the out-of-step condition experienced have been simulated by PTI,we will not subject our machines to the risk of damage by operating above the limits specified,except on a case-by-case basis. The comment in regards to weather conditions at the present beingmoreconducivetotestingisconfusing.With the low summer loads,especially on the Kenai,testing has been restricted in an attempt to stay close to the export limits and within the abilityofeachutilitytotakethetestpower.Voltage control on the Kenai due to these loads and the power transfers has been extremely difficult.As loads increase,testing should becomeeasiertoscheduleandperform. If there are any questions or comments,please don't hesitate to contact me at 762-4610. Sincerely, x,'alanavideyPaslyities -- Manager,Facilities Engineering DWB/pna DWB5-MOEBS cc:M.Gustafson,SWEC T.McConnell,ML&P H.Nikkels,ML&P TCS members bec:D.Highers G.Bjornstad T.Lovas B.Evans M.Massin File 410 NO.9072635204 P.O!MLRP GENERAL MANAGER FAX ; File 70LJ Municipality of Anchorage Municipal Light &PowerTomFink,Mayor 1200 East First Avenue Anchorage,Alaska 99501-1685 (907)279-7671,Tolecopiers:(907)276-2961,277-8272 alc-7-91 WED 14:21 FAX TRANSMITTAL SHEET MUNICIPAL LIGHT &POWER ENGINEERING DIVISION FAX NO.(907)263-5204 DATE:August 7,1991 TO:Dave Burlingame,Chugach Electric Association FAX NUMBER:562-0027 | FROM:Moe Aslam,Chief Engineer SUBJECT:Bradley Lake Deflector Trip THIS DOCUMENT CONTAINS .__9_.SHEFTS (INCLUDING THIS COVER SHEET). IP YOU WISH TO VERIFY RECEIPT OF THLS DOCUMENT OR YOU HAVE ANY PROBLEMS WITH RECEIPT OF PAGES INDICATED,PLEASE CALL MARILYNNE AT (907)279-7671,EXT.5429. THANK YOU. Putting Energy Into Anchorage 9072635204 oa-n7--a!no-2779u pnnt #29 R=95% CHUGACH ELECTRIC ASSOCIATION,INC. July 25,1991 Alaska Energy AuthorityPOBOX190869i 701 East Tudor Rd. Anchorage,AK 99519-0869 Attention:Mr.Dave Eberle Reference:Bradley Lake Testing PTI Performance Studies Dear Dave: Enclosed are the DSM plots from our Bernice Lake and ML&P 230 kV Substation DSM's.The plots are annotated but it should be noted there is a sampling difference between the two recorders.The frequency excursions shown after the system has returned to 60 could be load restoration in systems other than Chugach Electric Association,Inc.'s (Chugach's),however our SCADA readingsindicateChugachloadrestorationdidnotoccuruntilafter the frequency was decaying from 60 Hz. I understand SWEC has forwarded the plots recorded by the Bradley Lake DSM to Power Technologies,Inc.(PTI). Our concern with both this event and the unstable exciter event are that they were not predicted by the PTI studies.PTI has been unable to create the growing oscillations of the exciterinstabilityusingtheirsystemmodel. The system conditions for the unplanned unit trip of July 20,1991 appears to be fairly close to the case BTRIP60A studied byPTIintheloadrejectionstudy.In the PTI study,systemfrequencydecaystoonly59.52 Hz and frequency or poweroscillationsarenotpresent. In the actual event,frequency decayed to 59.23,0.3 Hz lower than anticipated and most likely would have decayed further had Golden Valley Electric Association,Inc.(GVEA)and Chugach notshedload.The plots also show a great deal of oscillations between the Beluga and ML&P or Bernice Lake units not indicated in the PTI studies. 5601 Minnesota Drive «PO.Box 196300 «Ancnorage,Alaska 99519-6306 Phone 907-563-7494 «FAX 907-562-0027 Alaska Energy Authority Mr.Dave Eberle Bradley Lake Testing-PTI Performance Studies July 25,1991 Page 2 The source of these differences is unknown,however the differences between the predicted and actual results are quite large.. We appreciate your help in attempting to resolve these discrepancies.Until the system model has been modified to reflect actual system conditions or the system anomaly corrected, Bradley Lake will be restricted to an output of less than 45 MW. If there are any questions,please feel free to contact me at 762-4610. Sincerely, CHUGACH ELECTRIC ASSOCIATION,INC. LoS Lod -David W.Burlingame Manager,Facilities Engineering DWB/pna DWB4-AEABRAD Enclosures Generation conditions 7/20/91 trip Note -The unit trip occurred at 12:07,GVEA and Chuzach were transitioning through a large schedule change and therefor exact unit loadings are unknown. Generation on-line Chugach Beluga 3,6,7,8 ML&P 6,7 Eklutna 1,2 Bernice 3 -3.3 MW 4<-7.78 MW GVEA North Pole Chugach shed 12.2 MW at the following schedule IGT 59.3 Hz 40 cycles -4.1 MW 59.3 Hz 55 cycles -3.9 MW Univ 59.3 Hz 45 cycles -4.2 MW HL g,arore Fryyery 60,04 yo wre OO”ATV FT \ e924 \\6770s ©126.0% caneevnn tee 3,65 we |ewn ea ee aa \ ° \-f& c - ;2!pe c3,4 y 51.3""af?os yatta " * ; ,*'uf te £J J J + be fee! 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H,o4 as@ Ce }'af ral||ye Whato,"err mov 7.78 6.4/4"7.90 He C%CaisMm ©3572.3 recodt iis FY.-9,71?aeJcuss "O73 H4 &/Ig ||"\|!]i i i ! j.0 W010 fee al if 00,d Lect 0 evn, EAENET HR DETONT PERRO TTE ETE RPCOETN TUT PE RTNTE MET TURIN SUELO OTERS AT EUOTERERTOTE NTP BOOED RPT RATTLE NFER STEN RTP PCTT OT PNT TOT EPI OT ITDshade583gece55. O -Soo bes |oye Berelsoeshguyts}Sov-/:/>7) sie [4 ney fo.?Js."wey Lp *s re Lule 7/21 [aD EiGGsce O00,1 FREQUENCY et c4,4-|fr i.dj j j l I {iiesLUtLsT 1 i]i]Lf v v 3 Ld {zoo ,o {ehh ,Q rooo,) RENT HRN TETRA STAN TRE LE TETR NTI'M ET Hg"rNG ARS ROME TOL RETRO HWE RR ERIE NPE ORR GER OND!CRUG OE EIEN R ERT TRE ON TRIER HUT OTT OOTT TE Trot WY - = Municipality of Anchorage Municipal Lightt&PowerTomFink,Mayor 1200 East First Avenue Anchorage,Alaska 99501-1685August1,1991 (907)279-7671,Telecoprers:(907)276-2961,277-9272 Alaska Energy Authority P.O.Box 190869 701 E.Tudor Road Anchorage,Alaska 99519-0869 Attention:Mr.Dave Eberle RE:The Bradley Lake Deflector "Trip"of July 20,1991 @ 1207 hours Dear Dave: Thank you for the copy of Dave Burlingame's letter (Attachment 4)and attached charts (Attachment 4 to this letter)relative to the Bradley Lake 60 MW load loss on July 20,1991.We share Dave'sconcernthattheprojecttransitiontocommercialoperationwith minimum disruption of service and with no undue risk to the Bradley system itself and the Railbelt intertie systen. In looking at the facts surrounding this particular occurrence at Bradley: 1.It may not be as similar to the PTI study case PTRIP60A as Dave Burlingame first thought.ML&P had Unit 7 on line instead of Unit 8 in the study.John Smith of the SWEC office at Bradley said the generator did not trip off line. Instead,the generator remained attached to the load while reverting to a spin,no load mode triggered by an improperly set bearing tolerance sensor. 2.At the time of the occurrence,the available spin on CEA's system was over 80 MWs and that of ML&P's was 37 MWs.This exceeded the calculated intertie spin requirement by at least 20 MWs.This excess spin and the intertia present on the system would at first glance seem to be more than enough to recover frequency without the need for the loadshed that occurred.Close scrutiny of the first frequency plot in Dave's package (the 230 KV line,0 to 700 cycles)does in fact indicate that system inertia had stopped the frequency decay at the 200 cycle point and before loadshed (approx.20 MW)occurred.His data would indicate that loadshed policy, and not system response to the 60 MW loss (from potentially any source for that matter)was the immediate cause of the interruption of service to some CEA and GVEA customers. Putting Energy Into Anchorage 3.Not included in the data that Dave sent you was the individual responses of the generating units on line at thetimeoftheoccurrence.Since this would be useful to verify proper governor response,we have included our Unit 7responseatAttachment1.The data indicates that Unit 7governorresponsewasaspredictedfora3%droop setting.The slight dip in the output just after 4 seconds is most likely attributable to the governor response to the rising frequency which stabilizes at 59.7 Hz and is then fully restored when tieline control intervenes at approximately 45 seconds.The Graph at Attachment 2 shows the rapid response of the ML&P system to the emergency demand produced by the Bradley Lake occurrence.Freeze data for the plots are in Attachment 3. As a result of the above,it seems premature at this stage to conclude that the incident at Bradley on July 20th calls into question the PTI study,or is by itself compelling enough tosuggestrestrictingtheBradleyoutputto45MWs--especially when the weather better lends itself now to the risks of the test program.The Bernice CTs response to the occurrence needs examination by the TCS for the large swings shown in the DSM plots.In order for TCS to have PTI examine this occurrence, additional facts and data from the interconnected utilities at the time of the occurrence would be required for an analysisthantheinformationsubmittedinDaveBurlingame's letter ofJuly25,1991. Sincerely, Moe.Ae aI Moe Aslam Chief Engineer MA:mgl Attachments: (1)ML&P Response to Emergency Demand (2)ML&P Freeze Data (3)Dave Burlingame Ltr/Attch. xc;Marty Gustafson,SWEC TCS Members Thomas Stahr,General Manager,ML&PTimMcConnell,ML&P Hank Nikkels,ML&P ma -24 UNIT 7 OUTPUT 7/20/91 1207 HOURS UNIT 7 OUTPUT (MW'S)INTERCHANGE (MW'S) 75 0 70 7-5 65 1-10 60 7-15 55 1-20 50 1°25 45 -30 0 20 40 60 80 100 120 140 TIME IN SECONDS --UNIT 7 OUTPUT SOURCE:FREEZE DATA --INTERCHANGE ra vo TmLege()a BY (E | °UNIT 6 UNTT 7 UNIT 8 EkL S.EKL |.30 LINE COUGL AS 11 62/FREQ 20-Jul-1971 12306304 0.09 -29.31 -51.,16 0.18 24.28 3.52 -29.48 in.g4 -23.71 37.78 20-Jul-1791 12306309 0.09 -20.31 -S1.16 0.18 24.25 3.52 -20.48 12.24 -238.91 So .78 2O -Jub-2197E 12205514 '0.99 !9.87 "52.43 0.18 23.82 3.52 729.94 12.66 "79.71 59,748 29-Jul-1991 12506517 9.99 19.87 -51.43 9.18 23.82 3.52 -20.04 11,44 -28.71 39.96 -*No lata ¥- 2O-Jub-1991 12506827 0.09 -19.87 -50.81 0.18 23.82 3.52 -20.48 12.31 "28.91 59.95 20-Jul-1991 12306334 9.09 -19.37 -50.99 0.18 23.82 3,52 "19.98 12.17 -28,91 59.99 20-Jul-1991 12306339 0.99 -19.87 -50.979 0.18 24,26 3.52 -29.48 11.82 -28.91 59.95 20-JIul-£992 12305344 0.99 -20.31 -50.99 0.18 24,28 3.098 -20.48 13.98 -28,.91 59.94 29-Jul-1971 12305349 ..0.09 "19.49 -50.99 0.13 24.26 3.52 -20.48 12.59 -28.91 57.9% 20-Jul-1991 12305354 . 0.09 -20.40 -50.99 0.18 24.24 3.52 -20.48 12.38 -28.91 SF .9F 20-Jul-1991 12305!59 0.09 -29.49 -$9.9?0.18 24.28 3.62 "19.98 12.87 -29,24 59.99 20-Jul-1991 12307304 0.09 -29.13 0.18 24.26 3.52 "19.98 13.22 "29,28 SF .8F 20-Jul-1991 12207299 0.09 -29.13 0.18 24.26 3,52 19,78 12.73 -29.26 59.79 29-Jul-1991 12307314 0.09 -29.13 0.18 23.82 3.52 -19.78 13.29 -279.26 SF .99 2O-Jul-199L 12207819 0.09 -20.13 0.18 23.39 3.52 19.25 13.71 -29.26 59.98 - ¥No Data *- 20-Jul-1991 12307329 0.09 -20.13 0.18 23.82 3.52 -19.49 13.36 -28.91 69.00 20-Jul-1991 12807834 0.09 -20.13 0.18 23.82 3.52 -19.08 12.94 -28.71 59.98 20-Jul-1991 12807839 0.09 -29.40 0.18 $1.25 -4.92 -60.22 8.23 3.890 59.33 -*No Data *- 20-Jul-1991 12307245 - 0.09 "19.96 64.7 0.18 49.76 -3.78 -9$5.47 1.55 0.35 59.71 29-Jul-1991 12307854.sy0.09 19.96 '} 61.89 0.18 49.23 -3.78 -56.00 -9.79 0.56 S9.73/ 29-Jul-1991 12307359 'coat 0.09 "19.96 |[-61.89 0.18 48.62 -3.78 -56.00 0.07 0.56 $9.73 20-$1-1991 12:08:04 |9.09 -19.96 |/-e1.98 0.18 48.42 "3.34 55.12 Q.42 0.56 59.73 29-Jul-1971 12:08:09 \. 0.09 "19.96 -61.19 0.18 48.62 -3.34 -55,12 1.41 0.54 59,7329-Jsl-199L 122938214 a an ou 0.99 29-Jul-9912 0.99 20-Jul-1991 0.09 29-Jul-179t9.09 20-Jul-1971 9.99 29-sul 1991 9.09 cO-Jub-1F91 0.09 20-Jul-1791 0.09 29-Jul-1971 0.09 29-Jul-1991 0.99 20-Jul-1991 0.09 29-Jul-1991 9.09 4 No [tate * 29-Jul-1991 0.09 29-Jul-1991 0.99 29-Jul-1991 0.09 29-Jul-1991 0.09 29-Jul-1991 9.09 20-Jul-1971 9.99 29-Su l-1991 0.99 20-Jul-1991 0.09 29-Jul-1991 0.09 20-Jul-1991 0.09 29-Jul-1991 0.09 29-Jul-1991 0.09 20-Jul-1971 29-Jul-1992 0.09 0.09 29-Ss L-1992 0.09 29-SUL-LF9t 0.09 20-09-4991 9 99129-, bao.o.0 -29.48 23035297 12509329 22.58 123997334 -23,12 12309239 -23.12 12307344 -23.12 12307349 23.568 12309854 -23.56 12307359 -24.00 12319504 -24,00 12310:09 -24,.00 12510314 -24.00 12319:19 -24.09 12319224 24.00 12310329 24.00 1219TA-24,00 12219339 -24.909 1219844 -24.00 PW1r9osas -24.60 1210254 -§1.89 -61.27 61.89 -63.21 63.74 -$3.74 63,390 63.390 64.99 "43.54 63.56 -56, "576 97 67 29-Jul-1991 0.9? 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"3,52 -55.03 -3.82 -S5671 -2.98 eroe -3.96 -57.23 -3.96 -57.23 -3.96 87.23 -3.76 -57.23 -3.52 £S.97 -3.52 -55.97 -4.12 -57.6? -4,13 -52.37 -4.13 -53.37 -4.31 -58.99 -4.31 -58.99 -4.31 -58,55 -4.31 -58.55 -4.31 -58.99 -4.31 -53.97 -4.31 -89,43 "4.31 -38.99 -4.31 -56.9? -4.31 -58.99 -4.31 -58,02 -4.3 -57,a¢ 69.9) 69.99 $9.90 $9.99 Vice ASIAA -(ity CHUGACH ELECTRIC ASSOCIATION,INC.paged ASSOCIATION iC July 25,1991 Alaska Energy Authority PO BOX 190869 701 East Tudor Rd. Anchorage,AK 99519-0869 Attention:Mr.Dave Eberle Reference:Bradley Lake Testing PTI Performance Studies Dear Dave: Enclosed are the DSM plots from our Bernice Lake and ML&P 230 kV Substation DSM's.The plots are annotated but it should be noted there is a sampling difference between the two recorders.The frequency excursions shown after the system has returned to 60 could be load restoration in systems other than Chugach Electric Association,Inc.'s (Chugach's),however our SCADA readingsindicateChugachloadrestorationdidnotoccuruntilafter the frequency was decaying from 60 Hz. I understand SWEC has forwarded the plots recorded by the Bradley Lake DSM to Power Technologies,Inc.(PTI). Our concern with both this event and the unstable exciter event are that they were not predicted by the PTI studies.PTI has been unable to create the growing oscillations of the exciter instability using their system model. The system conditions for the unplanned unit trip of July 20,1991 appears to be fairly close to the case BTRIP60A studied byPTIintheloadrejectionstudy.In the PTI study,system frequency decays to only 59.52 Hz and frequency or poweroscillationsarenotpresent. In the actual event,frequency decayed to 59.23,0.3 Hz lowerthananticipatedandmostlikelywouldhavedecayedfurtherhadGoldenValleyElectricAssociation,Inc.(GVEA)and Chugach notshedload.The plots also show a great deal of oscillationsbetweentheBelugaandML&P or Bernice Lake units not indicated in the PTI studies. 5601 Minnesota Drive e PO.Box 196300 *Ancnorage.Alaska 99519-6300 Phone 907-5<¢"-7494 @ FAX 907-542-0N27 Alaska Energy Authority Mr.Dave Eberle Bradley Lake Testing-PTI Performance Studies July 25,1991 Page 2 The source of these differences is unknown,however the differences between the predicted and actual results are quite large. We appreciate your help in attempting to resolve thesediscrepancies.Until the system model has been modified to reflect actual system conditions or the system anomaly corrected, Bradley Lake will be restricted to an output of less than 45 MW. If there are any questions,please feel free to contact me at 762-4610. Sincerely, CHUGACH ELECTRIC ASSOCIATION,INC. Lr BoeraManager,Fac Fifgene Engineering DWB/pna DWB4-AEABRAD Enclosures Generation conditions 7/20/91 trip Note -The unit trip occurred at 12:07,GVEA and Chugach were transitioning through a large schedule change and therefor exact unit loadings are unknown. Generation on-line Chugach Beluga 3,6,7,8 ML&P 6,7 Eklutna 1,2 Bernice 3 -3.3 MW 4-7.78 MW GVEA North Pole Chugach shed 12.2 MW at the following schedule IGT 59.3 Hz 40 cycles -4.1 MW 59.3 Hz 55 cycles -3.9 MW Univ 59.3 Hz 45 cycles -4.2 MW ns'N2= Dam =tis ArfcADY Berw Forward To AA ertTil By pave Bukuncame- HL FW)o gore foryery L AIO Kv bus Elcuess oto.d FREQUENCY io”£7 se HEE Alt -perenne /\'|\\rte|wa 54 70%5.FreeSrcarorcme2°e 19t oan t .an\eeTTTee oog eet'150 we 7Naa'Pal'-|- Cag \r wa IW t ra we \r }1 .,\'wtcy”10 °1! .grit as .S °Le y ' 4 st ot iv J sd J 's hates J d be"we\.4 »?ret °t } ty A ro e «st ydwsye3- =fol pb 2°c 4 !£"Jl .Gtsh\ot”P) ||}} b0 Log.et.200.0 Gon,BOO.0 boo.Pog HAT TTT TTT OT POET SOPOEVCTTTT UREN TREASON PTZ ET SOPOT £0,o- Sir l I j |1. \ ca4-\ #f 7 $4,711 €63.0 secant Lae L i !I pyreLXeadro S191 @ 379 S seve SEOFIME BS seconds i i i }|l"100.0 {00,0 300.0 £000 1700.0 ©6900,0 «$4a0,6 -Sele Change "qh,"4chtid 47000 1 - coo fre) ,y je hy Tree taeMi¢h ? /11L.CE ASO AV Trans for er V/acl/e ao/7, WoecosC Cede SEM dels 4a : gvfo,0-7 el pe!1f v ot Mt"yop ©a we18I_”/ae °¢?gett|re SM bool 1"gown ©nl )ceA eo ,07 |kK oa gs.ee" _Ad {$0,056meyneemedd Ot YL a os me |\4O,04 <5"\Crewee?qa ad gi”ATRL e! 37,996ae@€lay céEd Leedshed { 5 4 e oseellsat17,574'0eesane© !I I }L 4 i 4 i {l1 Va)e0u.g HOO.BOO t S000 1000.0 1200.0 Brod Saye cue ve tle ss 3 14,65 14,95 MG 5 12,07 y.s7 C88 cals \3.244eIt 3 ae|rl i Ll.||i j 1 'n \4d ,0 $6 $e00,8 (00,0 S000,0 #Si wenlll fps.7 wi 1)nonnnrnlisghle a a as TRS N RONAN ERIE TBE OR GURU THT PRT IN RETIN IIS FREI TRY TG ET RUT IPL ETI TT a pO Wodeor Lege Sk O UEC Ges 3reeCeedaeCeoheRiaeneeereettayee?mon er ie eT n,n ee ee or or ry -ee ee,ee ee tort not oT ee cd MeDR OefeteON Me tsre OM ee nT i 4 iM :ste 18.640e12!\°/at _-|;{iH t I "4 ||923 hc ;/7 87 set|oo| A |NY ",'.*Ld rkWAMeef oni CLG mw Mh/0,57 1H Cass h Hy -a,J 76aote eis o C 'WW bh 4 4 4 REE pent.Lad |7 SAR ORT er eregE ame Jroemanenacsrenee nen [-Pore)a ereea .{4 nyu Kon,o os eon 0 Loot a {ego ,0 endo0e "-'1Aiaaaceyrppanemspennyhteemagerenrnnmnemeamnnienodieopener o:i i aa A a a i ll ll | BLP #7 Uv ro °V/at Te, r y Ma ul la le Bie RTT OR NTETFEE TES PRTE ED SOW TR TENE STEW NET PEW CETREY Cm OTT TPT YTWateintbetpeeeedsW430)oF oe or ee ee Oe ee ey promnes "Er sep fit a {te 9,38 {Mt 1a ron @ ver cr |anil | stage”22°7 i!en | fe Pe |NATL By prob dart |MTT A Aarne We SarsNin7 Pm ang.y |Hit |amet wr "ibang wet wi lll Line a2 F jue Cit (-0.287¢01S°[ 0.07 1.07Clu fo Ie "2.64"1.68 CIsy C136 "Ef tae woe cr ene ee aoe ee ree Le ee ee en es Pee no Wino Gil we ECC ton 4 {eon ,0 eee ttiknahinaAiaelnodaathisraga§thd$900 emeereerrmmmmnearererenar EO Ce mre pTTT pFeNTl Lf* Wotsinttede SEO PETE W200) .f7Iebllypostie?¥pared uc 'nr i |ns4Yo |Mi f"arPert"e f*mildovo376ae|og ace |@ 903||vs ,wf '*20m 'ra.|A W\eee Wes b M tend |esr *ya/sg \.fi 'it Pt -O.60rmYnyupeg.2°@ 77%see@AM 0.24 L434e96|are 1)wd -1.80 udcienueejsar a eee wd ese meefe |,b semesnermrh b fone fens -nia in asvetoed pany H {e000 ,0 1600.0 engd ,t TO A a I ialle ll a CUA emmammeerememn!eba aa "Tr eF7nv rere wea L Meg rep fa iuaien peepee eterearenelreammieeinarenpe ae ateomecremmemnenaannasnsanemenmnemnamsnnnennanenenennmemmnanaenamamaas macnn,Eigssse 0000.1 FREQUENCY pure 7@ Free? bd7 57.707 ©q007 C re7iee bia -tier tend Fas ey ¥{|¥nal”y|9.760 eu 54 797 af | |agnssee gaat y, ,'e IST.S Secuds|f zw aa |an 4 £4 i $4,648 e |i |a hd Pa €Yo¥1 ere”Fs0.a4 " eure 376 jt S49.96e344one@lgivNf11€286” re rf __54.2?wie 7” SULAIUHO EE Nw ""it | -!i 4 {.0,0 ect .d 40.0 6 §3s B00.e000 Loo ,0 e000 &/- WeeecsCCedePSeddace-4) a23Ve mr ee?{4%v a es so a ©msef0 .fe'fe 'aad10"f "|19.17 re A |767 13.6 ee?|K re 7 @ [01 C5 SOT He _o.3¢©o7 Je .;2 74 fyWys:et Aah oe c a eJ yf We ah |25 tbey ™r4s /ene ¥,feu hte! -6.torr 070”c 26a.Ss see ea” we. oboJOelett "40,04 4 |l I |{{j l | @ oe #@ a.oo "-a,...2.:eee os r wear tH,o Han,o 5 ?fon ,0 {20,0 {eno ,0 eno,& PENRO RETNT TURE EIT PEER RETO TUTTE NOT TOUR ROTH ONT 1h PNCUNT Tm Lhp #3 Eigesse O00.1 FREQUENCY re Le hee 7/r Lad) Ble7 Rot tlds li Hil llli a ca, -|wn|! cy ud |fco.|VVJ f3.:"'v b..-|,a fonenoHOSsecMtut.1200.0 E00 ,0 cont) OAT THRE HTH RG NT EC OTUET ENE CY ROTTEN OS DONE N PGE RIT TRIPE ETT?1M NIUE NT Hf TY?RNIN CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska July 19,1992 TOs Bill Byrnes,Manager,Generation FROM:Daniel Rogers,Station Engineergy THROUGH:David Burlingame,Manager,Facilities engineeringSUBJECT:Power System Oscillation -July 14,1991 Attached are annotated Bernice Lake Dynamic System Monitor (DSM) recordings for the July 14,1991,system oscillation initiated by the Bradley Lake during unit testing.The recordings show the Bernice Lake units were subjected to significant power swingsduringthedisturbance.It would be advisable to inspect themachinesfordamageduetothisdisturbanceattheearliest possible time.If you require any additional information,pleasecontactmeatextension4752. ce:File 405,520.12,520.13 FregencyWeosuredofCHS138KYBus(Hz)O720ALL.avo Chart & Frequency measured for July 20,1991 Disturbance 59.8 59.6 59.4 59.2 59 58.8 "TTT 5 _ vm/| h 4 iV -g R 3 Sauples Page 1 O720AL..nuo Chart 2 Frequency measured for July 20,1991 Disturbance 60.2 60 a- 59.8 atege'>are ee=,nase o> &59.6 ' = sadin 59.4 w% a) Bp 59.2& >idbets 59 58.8 58.6 4 HHH x &®B&B RB =B &&®S&S B&B B FE _==-N "_" wn" Page 1 KilowatisoulofCHS81Bresker15000 10000 5000 -5000 -10000 O720ALL.XLS Chart 5 Load curve for July 20,1991 Disturbance 241481721Sasples 961 KilowstisoulofSHSB1Brecker15000 40000 O720AL Chart 3 Load Curve for July 20,1991 Disturbance 4819611241144168192121612401Samples Page 1 264128813121 O720ALL.XLS Chart 2 Voltage at the GHS 138 kV Bus for the July 20,1991 Disturbance 140.5 140 + 139.5 4 3'9F|=438.5 +a) Wwzm (O38 + 1) a S 137.5 + =>> 137 + 136.5 93.6 RHEEHEHEHE at431721961120114416a19212161240126412681 KilowalleoulofCHSB1Brecker15000 10000 5-5000 -10000 Frequency Vs.Load for July 20,1991 Disturbance O720ALL.XLS Chart 1 59.2 _59.3 _iT 4 rT t v LJ v v 59.5 59.6 59.7 59.8 Frequency measured at GHS 138 kV (Hz) Page 1 VoliogeofGHS136kVBus140.5 -- 140 + 139.5 + 139 + 138.5 =F 138 4 137.5 it"T137 O720ALL.XLS Chart 1 Load vs.Voltage for July 20,1991 Disturbance -10000 t t t -5000 0 $000 10000 Load at GHS BT Breaker kW (-=kW in to GVEA)-15000 OBOSFREQ.DAT Chert 1 e eenePPertretritr ts rete titre tttthrerrennet nn Shhhninnon oorpe eee LT] 4 ' e'SOSSSSSHSSEHRHACHSSEHSEASHSHTSSHSSOMADEETHESHACOHTT TSB C8S Oe oe 196 4''i] e't'See eee prec oervencee qe ae seaetererocnpenacoaeserepersen eecce ap a'''UJ 4 4 eee ee ee TY eS ee 4 a q'4 e t'Senswveca pears aercweer ae ge sen seeseceosemennsaereaesepurceewrenreece = 4 t ® Uj ee SS Be ene eee reof t ¢ e ' St te) ion oe i a Pewee wees Ce weg SFOs ateaeesione 4 i'L 4 ' Pere wees cemeqersseraaroucaeoe a 8 4 ''LY) Pees eocaccoesaqgersessesssesasee a 5'a J'awe man anc cndocnccecccecsiecs e e'$ ee Bene Sar L) ' a Rwwwew cence codwcaccaccccecionn a « a a '' a ' Lj 4 eeeeceeseosteesePe casescestboscenseeseadcaeneceerececaweeeocsnececescebaneneeneesop . . . e . 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' a a ' e '''''' beewvuvece Senawmenersevecteans wea weeecete wean eoeceeccedvccoerseecsweoecobeceessence ercobwewecases ens=e '' i] ''® '' 1 e ' ' OS6OS See wed es Sere Sse Ss eees cetesseeepeerwTessecwsegeseasesacesesePesscaasworepoeeceesseccsad '' ' '' t '' ' '' e ©Oe0Oe ww wag ec ees esc eS cases cee es ccs e pees eer eeecer grees et ete Tes per eraneneses pesceee ee cece ange ' ' '''' oe ee ce od cmc ewe n caine n men mn mmr epees ness cece teenc ecw ee wee scasc ccc ncn bec ew cee coe ape ' ' 4Lii ' LlLL1h. ai]11!1iL1L||a|ctlL{ dead LL LiTat1 t T T $ 59.6 59.4 59.2 58.8 58.6 OS8O3FREQ.DAT Chart 1 59.8 59.6 59.4 59.2 39 58.6 beebe2 080391 12:04 P.M,FREQUENCY 60.2°- 60.0% §9.8 4 59.67 59.45 $9.27 0.0 500.0 1000.0 1500.0 2000.0 2500.0 3000.0 080391 12:04 P.M.KWATTS -50000.07 -55000.07 60000,07 -65000.0°- 0.0 500.0 1000.0 1500.0 2000.0 2500.0 3000.0 080391 12:04 P.M,KVARS 20000.07 18000.07 16000.0- 14000.0- 0.0 500.0 1000.0 1500.0 2000.0 2500.0 300 ot0 141 140 -_wo138 VollogeofCHS136IVMoinBus&g135 134 O803ALL.XLS Chart 1 Voltage at GHS 138 kV Main Bus for August 03,1991 Disturbance 481961120124012641288121 MioutofGHSB1Brecker-70000 -65000 55000 -45000 itTO803AL!Chart 41 Frequency Vs.Load for August 03,1991 Disturbance Frequency measured at GHS 138 kV (Hz) Page 1 ¥ollageolCHS138kVBus141 140.5 -+ 140 + 139.5 + 139 --F 138.5 + 138 + 137.5 +4 137 + Load OBO3ALL.XLS Chart 3 vs.Voltage for August 3,1991 Disturbance -65000 4 1 1 T T T -60000 -55000 -50000 Losd on GHS B1 Breaker kW (-=kW into GVEA) -45000 GVEAENGINEERING907451-563822618:2797/3/31July 20,1991 Unsceduled trip of Bradley Lake at approx 62 MW PHASE B VOLTAGE MAGNITUDE”Gold Hill 138 kV main bus $39.55 1492.05 kV re ,Tedd 144.05 moat K | .pile hs 0.6 500.0 1000.0 1500.0.2000.0 P v 2500.0 3000.0 AMARA90745156381994% GUEAENGINEERING987451-563318:27e7/25/91July 20,1991 Unacheduled Trip of Bradley Lake at approx 62 MW |PAAwerePHASE C VOLTAGE MAGNITUDE Cold Hill 138 kV main bus $41.0- kv" $40.6- 139.85 139.0% £48.5- 0.6 500.0 1000.0 1500.6 200b.0 2500.0 3000.0 1N-PRawAT--7R-Qa19074515638R-94% GVEAENGINEERING987451-563810:26Or/31July 20,1991 Unsceduled Trip of Bradley Lake at approx 62 MW SN MVARS Messured st Gold Hill 138 kV Bl (Gold Hill -Healy 138 kV Line) a ee ee ome ee soe >948 8 °. °es tree ee nes emt Cn memes or crmmems oD OL te 5008.07 -6000.0- 7000.8" Ikilovara ”May 8600.0- . -9000.0-qt ly "1000.0.1 | -11066.075 3606.0Mgtt.t =t6.6 £60.90 1000.0 1560.0 2000.0 2560.6 penne 1N:7RaMPANNA#>2K07-25-919074515638R=94% July 20,1991 Unsceduled Trip of Bradley Lake eat approx 62 MW |PHASE f&VOLTAGE HAGNITUDE Gold Hill 138 kV main bus GVEAENGINEERING987451-563318:2667/25/9141.04 £46.65 kV taney | 138 165 137.85 0.0 500.0 1006.6 1500.0 2000.80 2500.0 3000.0 Neen eee ee eee eee reece aa AVT._9%F A+naanewaQN7451KAKARKR-95X% 18:2587/25/91July 20,1991 Unscheduled Trip of Bradley Lake at appr Sample Rate:GVEAENGINEERING987451-56381500 don't skip | H 59.441 | 800 skip 2 cycles berween samples 850 skip 5 cycles between samples 100 cycles pre-trigger 1208539000.8.FREQUENCY Measured at Gold Hill 138 kV Main Bus 60.2 eeeaeeraceeenscascesencssevensantaenensesasenerareesnnacuseuuseseavoasauacsensenooususseseusseceseseeeas B00 fag eesssessseetasensnanssneessatesseasnasnennasfinnnsnnensanavantosnareeasinnssegresesnressessats sssesesseseedencnssonsseeeeeed fesseesss rf MN sescescstesenteeseess Ppeseoevee OCPECeT PEI COCES TTT Terr rere rr reer ere r Te reer rere reer rrr ree terre tere eer rere ey PTET OTTTTTT TITLES TTT TUTTITTITITTTTTTTCTeTiTTTITTTTTTTTTeTTTTTTTTTeTTeTerrrTrrirrirreerrrrT rere poses scteseatecenssceessenesebonsseessseccssssncesnaeeseceessstaneesenaseaeesemnesnnessesnsesenenseess :':::: |ae oe ew :::@.¢@]506.8 1608.0 1500.8 2000.6 2560.0 3600.8 ReQh&X& GVEAENGINEERING98?451-5638G2310:26Or/25/91'July 20,1991 Unscheduled Trip of Bradley Lake at approx 62 MJ ceeSORTC32IECUZSWH4N3SNS)Measured at Cold Hill 138 kV Bl (Gold Hill -Healy 138kV Line) 16600.0% |- 1066.6-@.0 .$00.0 1500.0 2000.0 2500.0 3008.0 10:26AMPNNR#7607-25-919074515638R-94% O7/725/91 18:25 GVER ENGINEERING 987 451-5638 a1 CY GOLDEN VALLEY ELECTRIC ASSOCIATION INC.Sox 71249,Fairbanks,Alaska 9970/-1249,Phone 907-452-1151 R=-94% DATE: TELECOPIER NUMBER? PLEASE DELIVER TO: COMPANYs TELEPHONE NUMBER? PROM: ACCOUNT NUMBER? PAGES TO FOLLOW: TELECOPY TRANSNITTAL July 25,1991 562-0027 Dave Burlingame Chugach Electric Association,Inc. 563-7494 Steven Haagenson 107.21 7 (INCLUDES THIS COVER SHEET) REEMREWEEREKREEREKEEEEREEEEEKEEEKEEERHREREKEEKCREKEKEEEEKEKEEKEKECEEKETERE IF YOU DO NOT RECEIVE ALL OF THIS TRANSMITTAL,PLEASE CALL: NELANIE FERGUSON,452-1151,EXTENSION 241 EHEKKEKEKEEAEKEREEREHERAEEEERREREKEKEENERECREREERERETERETEEEEAREREEE SPECIAL INSTRUCTIONS: PLEASE REPLY TO:ENGINEERING TELECOPIER (907)451-5638 OR (907)452-1151,EXTENSION 638. 907 451 5638 O7-25-91 10:26aM Poni #78 oe pial A a a ae NN A A la A NO 0 ROS AS RR el a ee nl Ae RL em reeled Ltt at te lid LBELPPUnit4fatactivetpottyPCHodL468|NUAP -eome=.j-bee-_-ee-_----- =<,Ile yo{ "20,07 "40,07 Gg 199A WS Ge yn ae”27.4 /4VAr 2d!gee *{f i etd sf Good Bi,O AL. Dara MRS FOR EL)yrsro,,- ° :"a.COND TU SCO te tet e samp mer mec tc a tn 0 a a a ey ELPP Unit 4 powar 7/d4 791 24582 =Ml uit sho eu.07 io ,o- H f inityTd] '||;|\|: \Ty TIN \I \=ey aha*|i ||weeWfAdda||||1 | a |||_Won || Pram,t?Spe ;?;. Frav®26.600 ww fis a oe ia oe tet Bt ar 2.SIMW oy ree 4 | |son eto,d HOD 0 NOTE . Bato erel shsesia gee icons 4 at Ct tpna cam /:of. ELPP Unit 2 Raactive Power FSL4 29 14:fe =NVAP Yi)\tt " a 3 a,én Iefsi.||Lf)1 fi fr Niet bw MT /'f if rT ae on sone yet pao 5 eemmammnnntanains An ' | 1 |,||"ef \,¥,\|\1 a ' .\|"Ett .yeOnaxbal328.419 MVAr a |i (Owe \ Onin ©727.19 AMVAr @ 4 sec =U il l 1 L et fi fl sal fi a MOTE:DAM ALIALED FOR ne car Te seabeny Cha nix : Bt i if eeeeeee EP lOSee we fo [fA AAA A SR ORSAY CES EE OS NAG RTD 1 TEAR RR I SDA RRR STAN EyELPPUhit3powerP71409dT4sce=Mb Ui,tt 4 .B.«euiils *,*a we "a f .«Ttew I's Pou Fora MOE aca le c $3ev 440 A \'|f | -S.26Md $19" -18.701W@ 1b.5 Ste «2.27@ W.S5e- -£OorR £2 10S , Haste . da ta aliared oe to SOGC%.ake ei,0 Ui a if ay i iC oo [PMA RAL A RE I NN Ll MEM CWA PE Cn MA Rl 8 9 A A st ld ELPP frequency f7i49/94)14:82 =Hz bie RO eyb4 | t:#1I &*421 \ €<*Sto \ yt 60.10 &*510e \ a 573 22 C3S7 ce ,2.8.95 Hstury”3 =4S Sec Ld Ny Tmax”@O:19 ha ee fan bad $4.42 Hy ww ga 18 tee yn on-So7-/Sars 7 ton a Sf De 561 ,wf t nage .and edd,a Ui i if saan as Sana ae Ree OE OED WR NOL AANA YER AO LV SI,CO ER TO Hf AI RE YC ESOL OE A Pid LEON p00 VOTE : Faom 5 T on "Puya)wee Ie ABS0155A SCALE CHANGE (@ GOO I S4Yeye TO 254 Yhge (PZ \,/MeterfeNZ =,Municipality of Anchorage Municipal Light &Power/Tom Fink,Mayor 1200 East First Avenue Anchorage,Alaska 99501-1685 (907)279-7671.Telecopiers:(907)276-2961,277-RROETVED MAR 2 7 1991 Production Division March 18,1991 David L.Highers General Manager Chugach Electric Association,Inc. 5601 Minnesota Drive Anchorage,Alaska 99502 Dear Mr.Highers: Attached is a copy of a very recent article on the governing response of Bradley Lake.While this type of technical paper is very restrained it is clear that very poor performance is expected and large load swings will result in instab- ilities.I would be amused by the disingenuous excuses they repeat for not con- structing the project correctly (with a surge tank)if it were not for the fact that all our customers will pay dearly for this omission. The authors wrote another paper outlining a technical solution to some of the problems they discussed in this paper.I do not yet have a copy but it is quite likely some cost will be involved in obtaining proper governing response.While past actions of the BPVC in not recommending action to correct the projects governing response defects may compromise our position,I do not think we should give up on getting financial assistance from the State or the design engineer for any corrective action which may be required to bring the project's perform- anee up to acceptable norms. Very truly yours, a” a -- Thomas R.Stahr Recv'd.C&A Executive Office General Manager Enclosures \yMAR20°91 ee:Norm Story,General Manager,Homer Electric Association Ken Ritchie,General Manager,Matanuska Electric Associafié ROUTE T COPY MOLE Exec.Mane Acme Exec Mrer bun &man -_- =Mange One trv 1 =Mpinvee Rewrons 'Jonera)Counsot Governmem Sermons SOA asuetan 'Putting Energy Into Anchoragemnste ee rH "i>ee oeiaa, STARTUP TEST REPORT BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY SUMMARY A comprehensive testing program was performed on the turbine- generator units to ensure that they meet the contractualspecificationsandguarantees,and perform as designed.TheprogramincludedtestsperformedtomeetoperationalrequirementsoftheRailbeltUtilitiesasoutlinedbytheTechnicalCoordination Subcommittee. The test program was structured in three phases,Generic Testing, Preoperational Testing,and Startup Testing.Generic Testing and Preoperational Testing of contractor furnished equipment was performed by the various construction contractors under the direction of the Construction Manager.Preoperational Testing of owner furnished equipment,SCADA system and turbine-generator units,and Startup Testing was performed by Stone &Webster Engineering. The test program began with reservoir filling on October 30,1990. Generic and Preoperational testing occurred during the winter of 1990-1991.The transmission line and station electrical systems were energized in early January 1991.The units were turned over to begin unit testing in March 1991.Tunnel filling began on April 19 and was completed on April 30,1991,13 days ahead of schedule. Unit 2 was rotated the first time on May 15 and Unit 1 on May 18. The units were synchronized to the system on June 20.All testing to ensure that the units met their contractual and performance requirements were completed by August 29,and the units turned over to Chugach Electric Association (CEA)Dispatch for testing on August 1,30 days ahead of schedule.The station was declared commercial on September 1,1991,on schedule. There were two major problems encountered during the startup with the equipment.The governor needle sequencing control caused power swings of as much as 20MW when the needles sequenced from two to three to four to six needles in operation.The governor algorithmsweremodifiedandtheseswingsreducedto1-2MW.The turbine efficiency meet the guarantees at the peak efficiency point,but is approximately 0.7%low at full power.This problem is beingdiscussedwithFuji. TEST ORGANIZATION The test organization consisted of representatives of four projectorganizations;AEA,Stone &Webster (Engineer),Bechtel(Construction Manager),and the construction contractors.Theconstructioncontractorswereresponsibleforconstructiontesting,an@ Preoperational Testing of equipment and systems furnished bythem.SWEC and the AEA operations performed Preoperational Testing of equipment provided by AEA.Bechtel supervised and witnessed testing performed by the contractors and recommended systems for turnover to SWEC as complete and ready for further testing.Craft support for testing by SWEC was provided by the contractors at an hourly rate. The testing program was structured in three phases. Generic Testing:These tests were performed by the contractors to verify the quality of the construction and ensure that the equipment and systems are ready for further testing.These tests included wire and cable checks,hydro-testing,control circuit tests,piping cleaning and flushing,and system physical inspectionandverification. Preoperationa]Testing:Systems and equipment provided by the contractors were operationally tested and placed into operation by these procedures.The procedures included a step-by-step control system checkout and system performance test.PreoperationalTestingofequipmentfurnishedbyAEA,the SCADA system andturbine-generator units,was performed by SWEC in conjunction withtheAEAoperatingstaff. Startup Testing:Startup Testing consisted of those tests requiredtoplacetheunitsandstationinanoperatingcondition.TestswereperformedtoverifythattheequipmentandsystemsperformedasdesignedandasrequiredbyAEA.At the end of Startup Testingtheunitswerereadyfordispatchingbytheutilitiesandcommercialscperation.Included in this phase of the testing weretestsrequestedbytheutilitiesTechnicalCoordination Subcommittee to verify operation of the station on the system. A Startup Manual was prepared by SWEC to outline the scope of theentireprogram.This manual provided procedures and control for the program to ensure that the objective of a commerciallyoperationalstationwasmetattheend.The manual consists of four volumes. Volume I -Administrative Procedures:These proceduresdescribethestructureofthetestprogram,safety andjurisdictionaltaggingtobeused,and the jurisdictional turnover process to be used for control of systems. Volume II -Generic Test Procedures:Mechanical,electrical, and instrumentation. Volume III -Preoperational Test Procedures:Section 1 Procedures for the General Civil Contract (Enserch J.V.); Section 2 Procedures for the Powerhouse Contract (H.C.Price); Section 3 Procedures for the Transmission Line Contract (Newbery);and Section 4 Procedures for AEA furnished equipment (SWEC). Volume IV -Startup Test Procedures:For integrated plant testing and unit performance testing. SCHEDULE A schedule was prepared by SWEC in the fall of 1990 for testing and turnover by the contractors to allow testing of the project ina logical sequence and meet the contract milestones and commercial operation dates.The contractors'construction schedules did not allow for this preferred testing sequence,however they were able to meet key dates in the SWEC schedule.The testing sequence wasmodifiedtoreflecttheturnoverdatesscheduledbythecontractorsandthefinalstartupscheduledeveloped.Key early finishmilestonedatesintheschedulewere: Begin Reservoir Fill 1 Nov 90 Transmission Line Energization 30 Nov 90 Plant Energization 25 Dec 90 Tunnel Fill 13 May 91 Unit 1 Turnover for Preoperational Testing 9 Mar 91 First Rotation 25 May 91Synchronization17Jun91 Load Rejections 5 Jul 91 Commercial Operation 31 Aug 91 Unit 2 Turnover for Preoperational Testing 1 Mar 91 First Rotation 23 May 91Synchronization14Jun91 Load Rejections 3 Jul 91 Commercial Operation 1 Aug 91 These early dates allowed almost 40 days of slack to meet the September 1,1991 station commercial operation date. The Transmission Line Contractor was unable to turnover the line until late December 1990.Due to the Christmas holiday it wasdecidedtodelayenergizationuntilJanuary1991. 3 The Powerhouse Contractor had difficulties meeting its turnover commitments for the turbine -generator systems.This caused a late start of Preoperational Testing of the units of 12 days. Water inflow to the reservoir since the gates were closed was less than anticipated.It became apparent in May of 1991 that sufficient water would not be available to develop the head necessary to operate the units at full load for load rejection testing as scheduled.Water inflow was projected and coordination made with the utilities outage schedules and the load rejection tests were rescheduled for second week of July,depending on availability of sufficient water.: During June of 1991,the utilities requested that Startup TestingbecompleteandtheunitsbemadeavailablefortheiroperationbyAugust1.This required a rescheduling of the startup progran.After discussions with the TCS,it was decided to complete all startup testing necessary to prove the units by August 1,and that the tests requested by the TCS to demonstrate operation on thesystemwouldbecompletedinAugustwithcommercialoperationofbothunitsscheduledforSeptember1.The following milestone'dates were developed: Unit 1 Synchronization 20 Jun 91 Load Rejections 12 Jul 91 Acceptance Tests 25 Jul 91 Unit 2 Synchronization 20 Jun 91 Load Rejections 18 Jul 91 Acceptance Tests 22 Jul 91 Units ready for Dispatch 26 Jul 91 Commercial Operation 1 Sep 91 The following dates highlight the actual progress of the testing program. Commence Reservoir Fill 30 Oct 90 Transmission Line Energization 9 Jan 91 Plant Energization 10 Jan 91 Tunnel Fill Complete 30 Apr 91 Unit 1 Turnover for Preoperational Testing 13 Mar 91 First Rotation 20 May 91GeneratorInitialTests1Jun91 Synchronization 20 Jun 91 Load Rejections 11 Jul 91 Acceptance Tests 29 Jul 91 Unit 2 Turnover for Preoperational Testing 7 Mar 91 First Rotation 17 May 91 Generator Initial Tests 5 Jun 91 Synchronization 20 Jun 91 Load Rejections :16 Jul 91 Acceptance Tests 22 Jul 91 Units Turned Over for Dispatch 1 Aug 91 S9OMW Two Unit Run 14 Aug 91 90MW Two Unit Load Rejection 16 Aug 91 Commercial Operation 1 Sep 91 RESULTS The test program is documented in the completed test procedures turned over to the Authority.The pertinent data obtained is summarized below.Test results for both units are well within the gurantee or design values with the exception of the turbine 'effeciency. Unit 1 Bearing Vibration After Balancing (Maximum allowable 40u-m,zero to peak) Bearing Vibration Temp Clq Wtr Inlet (u-m,O-P) Turbine 0.4 133°F 40°F Gen Lower 2.5 115°F 40°F Gen Upper 5 118 °F 40°F Thrust 142°F 40°F Shaft Runout (Maximum allowable 4%bearing clearance) Gen upper -O3mm Turbine -O1mm Unit stop time (with brakes,without brake jet)-6min 30sec Generator Parameters Design Actual Direct Axis Synch Reactance (Xj4)0.80 0.75 Negative Sequence Reactance (X,)40 36.23% Zero Sequence Reactance (X))16 15.95% Short circuit ratio 1.2 1.33 Wave Form Deviation Factor 10%0.43% Telephone Influence Factor Balanced 70 2.6 Residual 50 .5.7 Heat Rise With All Coolers 75°C 63.5°C One Cooler Out of Service 75°C 72°C Load_RejectionsMax Penstock Max Load Speed Pressure Gen Volts (%/MW)(start /max)(start /max)(start/max) 10%/6.84MW 300/303rpm 482/491psi 13.31/13.458kV25%/16.63MW 300/306.8rpm 483.5/487psi'!13.46/13.629kV 50%/30.1MW 300/310.8rpm 478.7/502.9psi 13.44/13.529kV 75%/45.0MW 300/317.3rpm 474.3/516.6psi 13.2/13.497kV 100%/60.84MW 300/323.9rpm 464.6/518.5psi 13.22/13.484kV 1.Tested on a different day than others at a higher reservoir elevation. cienc Guarantee Actual] Turbine -Peak 90.7%90.57% Turbine -Full Load 89.8%86.1% Generator 98%98.2% Unit 2 Bearing Vibration After Balancing (Maximum allowable 40u-m,zero to peak) Bearing Vibration Temp Clq Wtr Inlet (u=-m,O-P) Turbine 0.3 132°F 43°F Gen Lower 3.5 122°F 43°F Gen Upper 3 125°F 43°F Thrust 142°F 43°F Shaft Runout (Maximum allowable %bearing clearance) Gen upper -04mm Turbine -04mn Unit stop time (with brakes,without brake jet)-6min 25sec The solenoid valves the Contractor provided on the air compressor caused water hammer in the small Service Water line.Surge suppressors were added at the air compressor skid.This eliminated the water hammer. Depression Air System -During full load operation of the units at high tides,it was noted that one depression air fan could not depress the discharge chamber level when one unit was operated at full load and the other at greater than 20MW.During investigations of the turbine efficiency,it was observed that the air requirement of the turbines is several times more than anticipated by Fuji.Discharge chamber level is adequately depressed by two fans,the second starts automatically whenthefirstcannotkeepup.This is adequate for operation. This problem will be resolved when the air flow and efficiency problems of the units are resolved. SCADA System -Several minor hardware problems were found with the SCADA system during testing.All failed parts were promptlyreplacedbyLandis&Gyr.There are continuing problemsassociatedwiththeVHFradiolinkwiththeremoteRTUs.The delay time allowed by the system was not sufficient to allow for the time delays of the radio repeaters.Landis &Gyr hasmadechangesinthesoftwareatthemasterandtheRTUsto increase the delay time.These changes have allowed VHF system to work on a sporadic basis.The present problemsappeartobeintheVHFandfibersystemsprovidedbyDIVCOM.There is a frequency conflict in the VHF system with a user in Anchorage.DIVCOM is investigating to solve these problems. Unplanned Load Rejections -Two unplanned complete load rejections and two load rejections to speed-no-load were experienced. The first load rejection was due to power system oscillations that developed when Unit 1 was at full load.The power systemstabilizershadnotyetbeenplacedinservice.It appearsthattheoscillationsweretheresultoftheunitexcitation system interacting with exciters at Bernice Lake.The powersystemstabilizerswereplacedinservice,and no further oscillations of this type were observed. Unit 2 was inadvertently tripped from full load when the governor was accidently shut off during a transfer to manual. A protective hood is provided for this control switch and all operations personnel familiarized with its operation to prevent a recurrence. The two load rejections to speed-no-load were due to the action of the generator over-temperature relay.The relay hadbeenwiredupwithoutthetemperaturecompensationcircuitin place.This combined with an extremely conservative setpointforinitialtestingprovidedbyFuji,caused the trips.The 9 circuit has been rewired,and the setpoint revised by Fuji.The first of these trips caused the deflectors to close completely,rejecting 60MW in 1.5 seconds.This caused severetransientsinthesystem.The timing of the trip to speed-no- load was reviewed with Woodward,and the governor changed to slow the load rejection to approximately 60 seconds. Generato icie -Generator efficiency was tested on Unit 1. At all points,the generator meets or exceeds its efficiency guarantee.Due to the acceptable results,the generatorefficiencytestwasnotrepeatedonUnit2. Combined cjen -Unit efficiency tests to determine turbine efficiency were performed on both units.The turbines are within tolerance at the guaranteed best efficiency point but do not meet their guaranteed efficiency at full output.See the attached curves.Fuji sent out a special team to investigate.They theorized that there was too much air being admitted to the turbine by the depression air system.The results of their tests indicate that the amount of air doesnoteffectefficiency.This issue is still being discussed with Fuji.Fuji has about nine months (June 3,1992)to implement a satisfactory resolution. Governor Needle Sequencing -During needle sequencing,large power swings,as much as 20MW,were observed during the needle transitions.These were the most severe on the two to three and three to four transitions.The needle sequencing method was revised,and the three-needle operating condition deleted. The loss of efficiency by deleting this operation is slight.After revision,the power swings were reduced to 1-2MW. Tuning of the CEA Dispatch SCADA system was done to reduce overshoot and undershoot when under dispatch control. Water _in Turbine Bearings -During Fuji's efficiency retest,water was noted in the turbine bearing oil on both units.The source of water was traced to condensation in the turbine pits,and leakage past the dowel pins on the deflector servomotor.Fuji has investigated the water source and designed remedial measures included sealing the dowel pins,additional ventilation,and a water detection system.The changes that can be implemented with the units on line have been completed.The remainder will be implemented at the next outage.The oil for the Unit 2 bearing has been replaced,andtheUnit1bearingrunthroughafilterpress. 10 Generator Parameters Design Actual Direct Axis Synch Reactance (X,)0.80 0.76 Negative Sequence Reactance (X,)40 35.90% Zero Sequence Reactance (X,)16 16.28% Short circuit ratio 1.2 1.32 Wave Form Deviation Factor 10%0.83% Telephone Influence Factor Balanced 70 5.1 Residual 50 2.9 Load Rejections Max Penstock Max Load Speed Pressure Gen Volts (%/MW)(start /max)(start/max)(start /max) 10%/7.92MW 300/303.2rpm 481.8/489.7psi 13.42/13.459kV25%/15.34MW 300/307.4rpm 481.2/487.9psi 13.44/13.659kV50%/30.96MW 300/312.8rpm 480.6/490.5psi 13.50/15.200kV 75%/45.36MW 300/317.7rpm 477.4]---13.34/15.031kV 100%/62.28MW 300/316.8rpm 466.1/519.8psi 13.28/14.060kV Efficiency Guarantee Actual Turbine -Peak 90.7%90.5% Turbine -Full Load 89.8%87.1% Generator -Not tested due to acceptable result Unit 1. PROBLEMS ENCOUNTERED -CHANGES MADE Cooling Water Systems -During Preoperational Testing by theContractoritwasfoundthattheServiceWaterPumpsdidnotprovidetherequiredflowof500GPM.Flows were measured using the ultrasonic flowmeter of 420 GPM.The pump manufacturer stated that the pump impellers could be lowered in their casings to increase the discharge flow.It was determined that decreasing the lower impeller clearance byloweringcouldbedetrimentaltopumplife.During the generator heat run and subsequent operation cooling watertemperaturesintheclosedloopweremonitored.Since all temperatures were within the design criteria it was decided that the pump flow was adequate and the impellers should beleftasis. During the generator heat run on Unit 1 it was noticed that the pressure control valve provided for the bearing oilcoolersfoughtwiththetemperaturecontrolvalveprovidedforthegeneratoraircoolers.To continue testing,the bearing cooler pressure control valve was placed at a fixed position 7 approximately 75%open.This provided a minimum of 50psigwatertothebearingoilcoolers.Subsequent discussions with Fuji have determined that pressure as high as 60psig (system design)is acceptable,however flow should be limited to the maximum design to prevent cavitation in the oil coolers.The pressure control valve has been manually positioned to act asafixedorificetomaintainthesecoolingflows. Hardware Failures -Two relay interface modules in the electronic governor of Unit 1 failed during initial testing of the turbine control circuits.The brake solenoid valve failed with the second relay module failure.It was determined that the relay modules were not rated for the brake solenoid current or for the motor contactor current in the highpressureoilpumpcircuit(120Vac).Interposing relays wereprovidedonbothunitsandthedamagedpartsreplaced. During generator short circuit retardation testing on Unit 1, overcurrent relays were damaged.New parts were provided and the relays repaired. Also,during generator testing on Unit 1,one of the generator CTs failed.A spare was installed,and new spare CTs ordered from Fuji. Spherical Valves -During Preoperational Testing of the spherical valves,it was noted that the proof pressure of the seal water aifferential switch was below the system pressure.New switches were obtained from Fuji and installed. Fire Protection Penstock Supply -During Preoperational Testing severe water hammer and valve leakage was noted in the Fire and Service Water penstock supply system.It was determined that the pressure control valves provided by the Contractor were designed for gas service and not suitable for water service.This caused the valves to operate extremely fast,causing water hammer and control fighting between the various valves.The valves were not designed for tight shutoff and thus caused system pressure to approach penstock pressure whenthefirewatersystemwasnotinservicecausingtherelief valve to open.Also,the Service Water sump refill line valve was significantly oversized,causing water hammer in the system when it operated,also causing the relief valve in the fire water line to open. The pressure control valves were replaced with tight shutoffvalvesdesignedforwaterservice.The sump refill valve was replaced with a smaller valve and restricting orifices added to reduce valve cavitation.the relief valve setpoint waschangedtoeliminateopeningonoperationofthesumprefill valve. waterij -The power tunnel gates have been provided with a fail safe closing circuit on loss of SCADAcommunications.SCADA communications failed late on night,and the gates automatically closed.Both units were running at the time,and the tunnel was dewatered down to the lower elbow before the units tripped off on reverse power.Due to incomplete communications circuits to the permanent facilities,the operators were not alarmed at the loss of communications.Several alternatives to the loss of communications gate closing circuit are be evaluated by AEA. 11 TURBINEEFFICIENCY,PERCENT91 89 87 BRADLEY LAKE H-E PROJECT TURBINE EFICIENCY TEST RESULTS BEST FULL EFFCY PT.POWER DATE OF TEST:AUGUST 3,1991 611IO HP -84,640 HP LIMITSIOF MEASUREMENTINACCURACYBAND|+/=1.0 PERCENT a | mS /GB NN>TB a -™is wos 5S )1Y__rr GENERATOR [POWER OUTPUT.MW 10 20 30 40 50 60 70 | 0 0 |40.6 80.100 TURBINE POWER OUTPUT.HP'000 TURBINE NET HEAD =1,100 FEET LEGEND: GE =90.7 %..GUARANTEED EFFICIENCY @ BEST EFFICIENCY POINT TB =90.4 %...TESTED EFFICIENCY @ BEST EFFICIENCY POINT GF =89.8 %..GUARANTEED EFFICIENCY @ FULL POWER TF =88.1 %...TESTED EFFICIENCY @ FULL POWER POWER TECHNOLOGIES,INC.ONE SIERRAGATE PLAZA SUITE 3408 ROSEVILLE.CA 95678 916 783-3566 TELEFAX 916 783-2086 TELEX 145498 July 10,1991 Mr.Marty Gustafson Stone &Webster Engineering Corp. 7677 East Berry Avenue Englewood,CO 80111 PTI/SWEC/108-L Dear Marty: RE:Bradley Load Pick-up Capability In Deflector Control Mode At the last TCS meeting,there was some discussion concerning the capability of Bradley Lake,when operating in the deflector control mode,to pick-up load under isolated Kenai system conditions.Previous studies associated with the surge tank analysis had shown that Bradley could provide at least 15 MW of load pick-up capability when both units were operating in the deflector control mode.However,the maximum capability was never identified. 15 MW of load pick-up capability from Bradley was deemed adequate for expected load pick-up and system restoration in the Kenai system.But, knowledge of Bradley's maximum load pick-up capability is important since it will establish whether the use of Bradley is a viable option for system restoration following black-outs of the entire Railbelt system.Moreover,it is important to know the maximum water deflection rate which should ever be employed at Bradley when operating in the deflector control mode.Therefore, we conducted a short study to identify Bradley's maximum load pick-up capability when operating in the deflector control mode.This letter report presents the findings of this study. This study was performed on a system representation developed from the August 29,1990 model previously used for underfrequency load shedding studies.Bradley and its associated transmission facilities were added in the model.Further,this study assumed the Kenai was operating as an isolated system.Only Bradley Lake generation was assumed on-line (both units)and it was supplying the entire Kenai load.The Bradley units were equally loaded to about 28 MW each,and both units were configured for operation in the CORPORATE OFFICES ¢1482 ERIE BOULEVARD «©PO BOX 1058 ©SCHENECTADY NY 12301-1058 ©518 374-1220 Vv Page 2 Mr.Marty Gustafson July 10,1991 deflector control mode.A needle bias was selected such that each unit was operating with all six needles fully open (i.e.,80.58%of the physical 214mm needle stroke).: Load pick-up simulations were then conducted based on this model to identify the maximum load which could be abruptly added to the system before the first underfrequency load shed point (59.0 Hz)in the Kenai system was reached. These simulations also considered operation of the Bradley units with twodifferentdeflectordroopsettings?;1%and 5%. The results are shown on the attached plots which show Kenai frequency and various parameters associated with each Bradley unit (e.g.,deflected flow, mechanical power,deflector position,etc.).The first set of plots (2 pages) represents the response of the units when operating with a 5%deflector droop setting and subjected to a 46 MW load pick-up.The second set of plots (2 pages)represents the response of the units when operating with a 1%deflector droop setting and subjected to a 49 MW load pick-up.The results are summarized as follows: Maximum Load Pick-up Deflector Capability Droop 46 MW 5% 49 MW 1% A third plot (1 page)is also included which shows a comparison of Kenai frequency for a 46 MW load pick-up when the Bradley units are operated with a 1%versus a 5%deflector droop. In summary,the load pick-up capability provided by the Bradley Lake units is quite substantial when the units are operated in the deflector control mode. However,this load pick-up capability is limited to less than the units'available spinning reserve when conditioned by having to meet minimum frequency objectives.The load pick-up capabilities identified establish a limit on the 1 The revised Bradley governor allows for two droop settings to be input.One governs the droopcharacteristicwhentheunitoperatesintheneedlecontrolmode,and the other governs the droop characteristic when the unit operates in the deflector control mode.The two droop settings can bedifferent. ">+ Page 3 Mr.Marty Gustafson July 10,1991 amount of water which would be feasible to deflect in anticipation of large load pick-ups. Based on the results of this study,the maximum water deflection limit which is feasible is that water deflection rate which corresponds to 23 MW on each unit.Further,this study demonstrates that the deflector droop setting has only a minimal effect on the load pick-up capability.However,the deflector droop setting does have a fairly significant effect on the amount of system frequency error which will exist within a short period (10 seconds)following a load pick-up event. Please advise if you have any questions concerning this study or feel that further investigation is required. Sincerely, John H.Doudna,P.E. Senior Engineer JHD: Enclosure cc:H.K.Clark SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON. KENAE ISOLATED. BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE. 46MW LOAD PICK-UP.S¥DEFLECTOR DROOP SETTING. FILE:E:\DEF-LOPU\46MW-DS.CHN DEFLECTED FLOW (CFS)]{300.00 So =0.0 | DEFLECTOR POS (PU)J[1.0000 Cr 0.0| !NEEDLE OPENING (PU)|[t.0000 -----+0.0] ACTIVE NEEDLES (f)!{10.000 mre enn °0.0 | |TURBINE MECH POWER [ow f{100.00 -----*0.0|{FREQUENCY (Hz)]{63.000 $8.000 | {reeee es |rT}1:2 1 :'| =1 :'-_ 1 :'por i =|.'4: .'| I .4 i :'|=H .'-_ .i]t ,'| ';' a 1 ;_C2ee A tto:toy -|;H _ '.'Ji}¢ .e1!|3y bot 'a ':'| .' \"'| = ,\_fo:ty ):' |=:H 2 |:' \.'\ {'' .'a Poi gO Z om '-"1.wtoer?|.--t-"""fF +]!I bd 24BRADLEYUNIT#1VALUES12JUL101991WED,TIME(SEC)SUMMER 1991 BASED ON CONDITIONS FOR 06/29/90.BRADLEY ON. KENAI ISOLATED. BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE. 46MW LOAD PICK-UP.5%DEFLECTOR DROOP SETTING.FILE:£3 \DEF-LDPU\46MW-D5.CHNDEFLECTEDFLOW(CFS){ [500.00 erste ->0.0] DEFLECTOR pos {Pu}] [1.0000 rere %0.0| |NEEDLE OPENING (PU)| 1.0000 re y rar| |ACTIVE NEPDLES {f)| {10.000 eeeree °0.0} TURBINE MECH POWER (MW)j j100.00 --¢0.0 | l FREQUENCY {HZ)| 163.000 ----_*58.000| |ll a ||jl i |{3 1 .'2:'|_1 '1 - '1 |Io:{ I Ly '|3 =':'4s :'| ('+ °¢\:'| -i}.t -_- ,4{,'| ''1 ''|3 .I :'_je fot ;| ''foo:ro bh |''- !''J ':'3 i}''|3 _:'2t.'|t :' .1 too 1 | = ;' _$o:1 pot '2 \:'|8 I .'7s .'\:'\ |'.' .t-_|.'\> roo Nebogdee|,-a7"4 !|:3.00001.000022324JUL101991BRADLEYUNIT#2VALUESWEO,TIME(SEC) 13:00JUL101991WED,10.0000.00009.0000UNIT#2DEFLECT&FLOWS7.00006.00002.00004.00003.0000TIME(SEC)3.0000SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON.SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON.Sol.:°,.it BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE.°4 BOTH BRADLEY UNITS IN DEFLECTOR patti tees46MWLOADPICK-UP.5%DEFLECTOR DROOP SETTING."oO 46MW LOAD PICK-UP.5%DEFLECTOR DROOP SETTING. FILE:£:\DEF LDPU\46MW-DS.CHN is FILE:E:\DEF-LDPU\46MW-D5.CHN 3 e)TOTAL UNIT Flom tors)|o-"TOTAL UNIT FLOW (CFS)-.|Ji000.0 Meee eee 6.0 |oe |1000.0 iTURBINEHEAD-GROSS (FT)1 32]|TORBIN®HEAD-GROSS (FT)-- ;sat1500.0 Se 0.0 |ph 1500.0 . |TURBINE FLOW (crs)}7 TURBINE FLOW {CFS)-;ry[1000.0 Gm neem e 00}4 fl $000.0 |DEFLECTED Flow (crs)|Fa DEFLECTED FLOW (CFS)a rc[1000.0 --_-=<0.0 |4 J1000.0 . |DEFLECTOR POs (PU)j oie DEFLECTOR POS (PU)|11.0000 "4 0.0 |11.0000 ----*: |tou 7d '|J |i g &|tout {||if 4.'3 ' z '3 B '| -'I '|Te Zz A '|,.'''|3--|'oe -t '|;|';*|.'.'.i]hs :|a 4 '.J i |t '|'t ':\; |8 ;|'t e _.-.-_''4 '|°4 t | 't . .uv "' 4 4 |2 2 |q ra 1 '°4 '}4 '2 4 ' ';|g &4 | -A 'tle -.tI{4 '||t '.t "'3 ,| |l °4 | 'I ''4:'|3 ''JA]'3 4 ' 'L me -.'dl '/ft ,/'4 '|\'t \/8 ''/+-A \/"4 -fl '/4 Se -'I sso _ae|we -_'l whee -<||a ae ||{|-f-,||J e J |a |I !cl,1 J ! a SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON. KENAI ISOLATED. BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE. 49mMW LOAD PICK-UP.1%DEFLECTOR DROOP SETTING. FILE:E:\DEF-LDPU\49MW-D1].CHN DEFLECTED FLOW (CFS)| [500.00 peewee =>0.0 | DEFLECTOR Pos (PU)J [1.0000 Wee ee ee *0.0 | {NEEDLE OPENING (PU)| [3.0000 -------0.0} ACTIVE NEEDLZS (8)j |10.000 @oteceee r)0.0 | TURBINE MECH POWER (MW)] 100.00 --------0.0] FREQUENCY (HZ)] [63.000 58.000 | rr es ns a w 8 pot '3 a roy 1 |:'.'|- "«a ':H!¥'|3 =1 .'-/2 Io:'|: ''ros 1 |3 -|:\-_e t :'| ': ' t ,ot |3 .: le18'pik ye4]3 --]:4 a ae 1 3 J \: .'a i}.|g 1 ''{* |;} a 1:1 |.|i e t Cadfo:i ': '3 nm !,}fosOY) ro 1 A rot ty g-t :'n |4 !.'ee\es See|_,--t-"fos {!3 11:26BRADLEYUNIT#1VALUESJUL101991WED,TIME(SEC)SUMMER 1991 BASED ON CONDITIONS FOR 06/29/90.BRADLEY ON. KENAL ISOLATED. BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE. 49MW LOAD PICK-UP.18 DEFLECTOR DROOP SETTING.FILE:BE:\DEF-LDPU\49MW-D1.CHNDEFLECTEDFLOW(CFS)| 4500.00 is =>0.0] DEFLECTOR POS (PU)] {1.0000 rrrereraes a 0.0 | {NEEDLE OPENING (PU)J J1.0000 -_---_Se wre ACTIVE NEEDLES (f}] }10.000 --------r 0.0 | |TURBINE MECH POWER (HW)j [100.00 --™€0.0] FREQUENCY [HZ)] [63.000 ---*50.000| |do.||}l J >|I 3 {,''3.'. |:'|'3 -poo ' . os ':i |¢ °q ' |¥'|'3 -|:':Hs .;!, ]'' .r q °to |:g -1 :\'oe t .'|':''t .'|3 =t ;'2?e 'a 1 8 '} .' .4{to r |i _!:'"Te4 t ''J ]:' '' ro:i |3 x :}21:1't 1 n 'i]3 ='t)-e .'nfo:ty boo 'g':'8 EZ l . '"I 'to 1A tos 3 ry |''a )'.'"eee"oom?*.°|.-.l !||3 326il101991JULBRADLEYUNIT#2VALUESWED,TIME(SEC) SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON.f KENAL ISOLATED.aunBOTHBRADLEYUNITSINDEFLECTORCONTROLMODE.oe 49MW LOAD PICK-UP.1%DEFLECTOR DROOP SETTING.x0 FILE:E:\DEF-LDPU\49MW-D1.CHN = ef) an l inTOTALUNITFLOWICFS)| [1000.0 Pree x 6.0 |oHTURBINEHEAD-GROSS (FT)},9[1500.0 soe 0.0 |BYTURBINEFLOW(CFS)]fy[1000.0 earn nmnree °0°]gH] DEFLECTED FLOW (CFS){Fa1000.0 --0.0||DEFLECTOR pos {PU}j x[1.0000 ----s 0.0} ;|toa]t Hi (|||}|3 Eyi]'3 .'7 |i '|3 5of1|"Te n \ .i]¥'|3 =4 }42 1 :|: .4|||3il\|TA. i!!|¢ a ;|i :'6"| - .''u4i|Pa =|ry |]%eo')''J ” :H 3i|a ) .4 i '1 _ '1 "Ie|i |x 'P t |3 .''bd .t "TA|;| "|¢ .i] =|'\& |oe :; .AY:/i -A ')73 |' :me 74ae_-.-1 ieee |!|elt,|{¢ SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON. KENAI ISOLATED. BOTH BRAOLEY UNITS IN DEFLECTOR CONTROL MODE. 49MW LOAD PICK-UP.18 DEFLECTOR DROOP SETTING. FILE:E:\DEF-LDPU\49MW-DI.CHN Lane TOTAL UNIT FLOW {CFS} 5 on 0.0 |TURBINE HEAD-GROSS (FT)J }1500.0 SS 0.0| TURBINE FLOW (CFS)J [1000.0 eda'°0.0 | DEFLECTED FLOW (CFS)f J1000.0 -----0.0| 1 DEFLECTORPOS (PU)| f 1.0000 ----4 0.0 | {toagd vl l (|{}|3 't '3 ; -,'_'t ' il \a '|3 -r a 1 ;| .é L || :'t '| .4'|3 -,awl'| |t :t | _|4 4 4 4 P.' Z )1 |3.q catij7 1 i .tb]'| =:'_|j | a]:'\3 = 4 '° .'Tre''! AY '1 '/ =''_]i 1 }A see - 4 wee -7 .!|oy |!cLl:,_l !J 3 0512WED,UNIT#2DEFLECT&FLOWS9.00003.00002.0000JUL101991TIME(SEC) ¢{ SUMMER 1991 BASED ON CONDITIONS FOR 08/29/90.BRADLEY ON. KENAI ISOLATED. BOTH BRADLEY UNITS IN DEFLECTOR CONTROL MODE. 46MW LOAD PICK-UP.1%VS.5%DEFLECTOR DROOP SETTING. FREQUENCY (HZ)-5%DROOP 63.000 FILE:E:\DEF-LDPU\46MW-DS.CHN ---7 7 $8.000 FREQUENCY (HZ)-1%DROOP 63.000 FILE:E:\DEF-LDPU\46MW--D1.CHN eo 8 58.000 ||4 || | \ )- | ! | 4 -_-|-_ \ ee - =-_10.0009.00006.00006.00004.00002.00005.00007.0000TIME(SEC)3.00001.0000239CYJUL1019911WED,DROOPEFFECTONFREQ POWER TECHNOLOGIES,INC. FACSIMILE TRANSMISSION One Sierragate Plaza Suite 340B Total Pages:3 Roseville,CA 95678 Fax #:(916)783-2086 Tel #:(916)783-3566 TO :Sam Matthews -HEA Dave Burlingame -CEA FROM:John Doudna DATE:July 12,1991 SUBJECT:Scope For Supplemental Interim Operating Study Cases The minutes of the April 3,1991 TCS Meeting identified some additional cases the TCS desired to have run as part of the Interim Operating Study.These additional cases are to explore the "possible differences between running all three Bernice Lake turbines"(as was done in load/generation Scenarios C &F)"versus only one turbine at the same output”. The minutes were not specific as to which single Kenai CT should be used in place of the three Bernice Lake units.Further,if the minutes are taken literally,the Soldotna CT is the only option for load/generation Scenario F.It is the only "single unit”in the Kenai capable of generating 29 MW;the combined 3-unit Bernice Lake output used in this scenario. To clarify the intent of the TCS and to better identify the additional simulations which need to be run,I have discussed this with each of you.As a result of these discussions, I have put together the attached study scope.Please review this and provide me with your comments and/or changes,or indicate your concurrence with what I have put together. GAOVe xc:Marty Gustafson Study Scope Interim Operating Study Supplemental Case Base Cases Additional base cases will be developed for load/generation Scenarios C &F;the scenarios which utilized Kenai combustion turbine generation.The following four base cases will be developed from the Scenario C &F base cases used in the original study. Except for the CT generation changes or changes in the Soldotna capacitor usage,all other aspects of the case will remain the same. Scenario C Case A)Bernice Lake Unit 3 on @ 23 MW Soldotna 115 kV capacitors utilized as necessary Case B)Soldotna unit on @ 23 MW Soldotna 115 kV capacitors off Scenario F Case A)Bernice Lake Unit 3 on @ 20 MW Bernice Lake Unit 2 on @ 9 MW Soldotna 115 kV capacitors utilized as necessary Case B)Soldotna unit on @ 29 MW | Soldotna 115 kV capacitors otf Disturbances Only a limited number of disturbance situations will be run on these new base case models.The majority of disturbances run as part of the original study produced insignificant system impact,and thus will not be analyzed in this supplemental study.The disturbances which will be simulated are: 4-cycle,3-phase fault @ Bradley on Soldotna 115 kV line 4-cycle,3-phase fault @ Soldotna on Quartz Creek 115 kV line 4-cycle,3-phase 1lt @ Daves Creek on Quartz Cre "115 kV line In simulating these disturbances,the following controls will be assumed to exist and will be used: a)Transfer tripping of the Soldotna capacitors (when used)for outages of the Soldotna-Quartz Creek or Daves Creek-University 115 kV lines and when Kenai exports are above 25 MW b)Cross tripping of the Soldotna-Quartz Creek 69 kV line for outages of the parallel 115 kV line when the total power transfer from Soldotna to Quartz Creek exceeds 25 MW. Opcrating Limits In order to parallel for comparison purposes the results presented in the original study,two -gets of operating limits will be identified.One set of limits will be based on meeting all critcria (such as presented in Table 1 of the original report).The other set of limits will be based on allowing some small deviations from the settling and swing voltage criteria (such as presented in Table 2 of the original report).In addition to finding these operating limits,Bradley's transient instability point will be identified for the Bradley-Soldotna 115 kV line outage. | CHUGACH ELECTRIC ASSOCIATION,Ire.rm:eMcmwe anchorage,Alaska ]duly 2,1992 TO:TCS Menbers j PP{ FROM:David Burlingane,|Secretary SUBJECT:Bradley Lake PNC keeting The PMC addressed the Kenai inmport/loadshedding issue by passingthefollowinguotion: PMC Approved Motion -Recozmend the TCS set the operating criteriaforBradleyLakebasedonHEAandSewardbeingsubjecttonomcrethanstageIIloadsheddingforanysinglecontingencyevent.STage-IY leadshedding vas defined jas 55%of the HEA load.This cperatingcriteriashallbeuseduntilsuchatimeasthafinalcperatingconditionsareadoptedbythePMC. The TCS was instructed to set the minimus Bradley Laka operatinglevelsbasedonthiscriteria.Using the dispatch and generationcasespreviouslysubmitted[to model Bradley energy,the TCS vasinstructedtodeterminetheamountofenergyavailabletotheparticipantsifoperatedvithintheguidelinescftheKanaiimport ' The energy study will be Mone in two parts,the first studyassumingnogasturbinesareoperatedontheKenaiexceptinthosecasespreviouslysubaitted,This study will assume that vhanBradleyLakewouldbescheduledbelowminimmsitvillbeturned off somatines or sometines it will be scheduled at nininmuns. .. The second portion of the study will assume Kenai area gas-firedgenerationigavailabletqincreasethecperatingwindowforBradleyLake. For both pats of the study SWEC will atterpt to match the desiredschedulessubaittedbytheutilitiesfirstandmaxinizeavailableenergysecondvhileuininizingspill. Attached is the final version of the PMC advisory memo vhichincorporatedcommentsreceivedonthedraft. Distribution:8.Matthews -loa °x.Aslax -MLEP8.Haagenson <=GVEA D.Calvert Seward J.Hall --MEA}B.Pherle -AEA Pile 410 STONE &WEBSTER ENGINEERING CORPORATION S500 SOUTH QUEBEC STREET copyAENGLEWOOD,COLORADO 80111 NO ADDRESS ALL CORRESPONDENCE TOPO BOX 5406,DENVER COLCA ADO 80217 $400 Wwe Twx 910 938-0108 TELEPHIOQME-303 741.7700 Fax 363-761.7676 LE 4 Pal _wu TELEX 4$440)RCA TELEX 28925)303.741.7671 pth aN soenane wc - tauaco"Me mcucaue en ocnven sauveewciecerovstontSweammarowocRECEIVED te gg JGS Mr.D.R.Eberle "G9 1581 July 8,1991 Project Manager ALASKA ENERGY pritnsAlaskaEnergyAuthoritySKAENERGYbuetunriTy J.0.No.15800.22 701 East Tudor Rd.WP 22A Anchorage,AK 98803 SWEC/AEA/2757 ENERGY FORECAST WITH MINIMUM GENERATION LIMITS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY _This latter summarizes our understanding of your request to run the Bradley Lake energy forecast with minimum generation limits on the Bradley Lake units. Two cases will be run. Case 1:Attempt to meet the utility demand curves while minimizing spill. Anytime the demand on Sradiey Lake drops below the sum of 45 percent of Homer load and 7 MW for Seward load the Bradley Lake units will be shut down. Case 2:Attempt to meet the utility demand curves while minimizing spill. Anytime the demand on Bradley Lake drops below 10 MW the Sradiey Lake units will be shut down.The smount of time that the units operated between 10 MW and the Case 1 minimum will be totalled. This total represents the requirements to run a combustion turbine on the Kenai to support minimum Bradley Lake operation. We will summarize the results of run and make them available before the next TCS meating. If you have requirements for these runs other than those we have outlined above.please call. Oi,fp a Hot ip)CORRES ne TIA | . Theodore Critikos Project Manager iwc amas 8 ©ee JY/TC/SWG a Bers7Gnet ry ..nee ----_-eave STONE k WESTER «MN000403.ere1/8L.001 ' STONE &WEBSTER CNOINCE RING CURPORATIUN CALCULATION SHE' CALCULATION IDENTIFICATION NUMBER J.0.OR W.O.NO.DIVISION &GROUP CALCULATION NO.|OPTIONAL TASK CODE PAGE. BAST of Homer plane TMW fo Sousand .Min,Birdy Grrl.(0 Aus Plooae AXS card the VeAuDs we nod yo ™TAS/@\.TRhore WA O ar ovrsrfeePreemeencuwe(Far Nwvembe (OMW weWwassingakFAM)The dtheun ts nar"Trl =|Canes Unde (2 woah maon-fur far Brakes."LabetsdaQ "0,”&Lioneu B ondWSLofALNee&oa Jara,fel"te COMANE demas Araonwuade Deutl andPwrGemuredion 4 5010 65 STONE &WEBSTER ENGINEERING CORPORATION CALCULATION SH&T CALCULATION IDENTIFICATION NUMBER Ln CALCULATION NO.JOPTIONAL TASK CODE PAGEJ.0.OR W.O0.NO.:DIVISION &GROUPrChLoading For Bradleg Pred” Mean ot Lf oe (UW ) 40,23 S35| 33,33 Va. Y5,3d wT.19 46.1\ 34.X0 43-70 £7.19 43.67 H-14 S/o +TN aK Coan 2S.13 BoB 31.00 DOSF 31.89 2B.60 OTIS &4,.7| Q6.22 28S] 2E.bS IS.| BRADLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWAROD,MIN.SPILL) SUMMARY FOR MONTHLY AVERAGE LAKE LEVEL (FT) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG =SEPTYEAR POD PADEE MEO SOD NNGS1)tt Ot timteee, eeeeee¢ dda adh a a ee}ATFKLAM™OCDBDBNMDAIAOAMDLFORMMOOOFOOMeee eA VENOM DOT OOOR HOME MOWE NOM OCOMNMODOFONO"-FANroMm eeeeee#eeeetkteees#sesetewere ees eee ewan e ee ee oe SNM FOMTADMMPFOOMOOMNOMAA="OONOO DM MNVUHOMOAOVIMMOIDMAIDTVUMOMMMmmYO mtmtontotototOIOE °o otot AAD AAAIAMADMUODVDMOVN"OVOOKKr NOON oe eeteeeeefermtmUchOOo wre eee ehhhOhOmPhhmOmhhcOChUclhlWDNOMNGOAOMAMOFODOONVNDOMAnonoePF MOO AADDDMOHODADOTMIM=AMMMM Hammam QGOO OOO esi OOOe - =o =mom - 1S OCHNAMNMI MMF DPO HMMAMOOMOOTMAVA eo eeo@eeeeeeeeeesteteee#nse @¢woe eeeee eee DFOMNMOSOBOSCONVNOMNONOAMA="AMBHOAMMOW MONDO DDDO DDG HDOVMODDODODAHriMaMOMiIimen M=MOQOoooooooesoo000oed&4otodotondondontextondontcutwatont xtADHK(§FNVNOOMOKsMAM OHOOM""FOMNANMHDANGOKMO eoeeee eoeeeseses ehfF© Oe Oe wo wm wm Oem ee eoeoe¢ee MP FMOOIOVNK OMAONMADCOMFOAMNMOOAKNAD MOANDD ODD ODODVDOVDDODDODOMi MOToIMEM mAmOOOCGC9OO990$Oo0O000-ontomot=out - =ototome ome AFMKMOL OO ADAM MI AMOMOAMADVNENVNENnNHE dled did TnaTe ee ee eeeeD oeensteert es DBDMWOOAMOOMMONMOTFAMOCOO COOMA AMHE PO FOASVOAPOVDADAAQVDAVDa VveMmMeonnenes met OM QOS *9000O-000 ott otwt0ndodotot=APMMONFAITFHOMAKMMOBDODOMeCVOOHMONNDO-eeoeee es eoeeeesee8e8 @@@@8B 8h eh hUrhlUc Ohl eevsees#FNUDAMAMNOSF FETCHOAMOKAOMONKLANOAAOAeS OOM HKAOMDDOMMODNO"DODNUMOMTONMNVeENM 8otototot©©tO HOMHI HOH O = mtotontoe = - CDM LOMMAOMDOECMFAIOMOMDIMMOCOD e oe eet eo ee wee ee ewe ehlc OOmhlc OhOMCChOhOCHhUC OCCHOmhUh OCS eoeee.s OPMMM SOMAONTOMOM MMAMONNERMTOMM MEO PON AINAHAMNOMKANMNNDOHDMOMEMMOMMOW}aOOOntotontotodondOtotWNDSEMDOKQOOOHCOLONMOSTreCeaommauMmeee. oe eee tee eeeeeee ete ew eth ee eeee¢ee FAOBDOES FHOD (OOO FItMAGCVAINADVNROWORM o=tentontontextontontord - =te-tFNLONMDLAAMKOMMEPFORHOMOCOKMLADMOow*eeoee oeeeeee8ef ©&&@@@wo we wo wo ewe eoeees DBDOMOMMOMM™OSCANTANOM FOOTNDNNEMOOMKOMNAQONMHANAIMMMONDFMOMUWMMPOMO88ekotontoF=Fontondntot atmotOEot = -_ otextoxCOANTOAMSKHMDOOMHTNUMDINUMOVRONOMoee3eesee#ee @8@@@@©Oe ehlUc hlUlcOhlUc hUcOhUc OCU! oso @se 82@@ SNOOP OOMTAAOMNOMMANMAOMPKeowwmoen DPM FNM MAMMA MANUANNM MS MMNATOMNOMMGTOMMm phaphapa hemapceian hen hananhanton henkamentard -Lentonter eeee tokamd = - =ototot - tos - ontontxtot DONO ANOS MOM DAOAUMTMOMDAOMAUMENYO MWO WOOD OOOO OP HmmmmMmmm OOWODGO OeaOkeatodododomeemtOtmdondemtemtntmedemt ontontoneome 1128.32ANNUALAVERAGELAKELEVEL(FT)= 37 BRADLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWARO,MIN.SPILL) CAse | SUMMARY FOR MONTHLY MAX.LAKE LEVEL (FT) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG =SEPTYEAR FROLNOADOMANOSONMOOOM=TOCNKMODddd a 2 eeeeneey eevs+eeie#ese SODMMAOA"OFTNNOMMTOMOOCNDCCOHOaH DW MOTNVMMFMONMAMFTONMOMOMDOMDONMWODorkeehen] Otemtotmdot phanhamhanLantand onondm8emtmt EK OMONDAL DOCOMO KMMMNUNFOOMODVNO=Aew eee eee es eee eee eee eaneewe eer eevee totwtIIOS FADE NGS AON HAO HOMOMMMIMMONAOTOMMMmO 5 in i ee erey oe eooe @@ MM MADNANS OMAMAMNSDOM MAME HRN etmeDFEVNMAIASODOHHM MIMNUAOIDNVNOOT AIM AMFTOoOw Hote OHM OOM MH ONO MOEN SOM FMMOTMAMAIMAMAAMNUNDeeene ttedttotAMM ODNUNGANONMAAKAAOMANOTOOMMOODcoeee ee ee ewe ese seeweeae oeeese 8s t@ee#es8eseWMONVEOOM9DODOAMHAOPFONMNOMTOOKRAMMPFONMDDHAODVBDDOAODWDOA VveEnamoeamee mmm OOOO O00"0-000HKHMMOMODMNOCNONENGCOOCAOAMDEAnNAaaawnses @eo eee ese eo @e@ se@ ees ef@@@© ee oo@ ee? eoeene¢NQNMMKWMDLFONOMIADOMOMOAMDATOONMOCOOF MOO DDOADOOANOADADNNEMTONWNENW MMVII MOO AIO MOK HIMOOO BMNOAOMODMMET DDDOANOND=@MHOANMAMO e° ee ©@@ ae ¢@ eoeeeersksee see ew ee @ ee Oehe SHAM AADO MOOR SO Dee NBs NOC OM MMMADOMNOOANAINDODNOMSEHOOMeTONMntntnttt SE tt IO I IONE tomtom ot 888okodomondodmtototot _ ASM ESMALOMMNAIOOOD--MMOrMOTCOOND eee eesete te e@eeeeerte e ees ee eeeeeese oe @ NOOO OOMMMNDAIDOCOMNOOO=AHK MOO PON MNODINOAMONNANA=DMMOTMMOMMHOOotmtotomoOCD foto=) oe BAA STOCNMNODOSEKMONHOMaAMAODOTNHOS haan ada ad dta eeeeeeeeeeee COMUMOOMM Se Sele eee eSawFOMNMOONMAAIAIMNMONDEMONMOMK ew o == tet o OMSK KMEMNMOOSTTANMNOCOMMrMOrCOMneonr ee e# oe eee#eee eee e eee ee#ee¢ eoee#ee emmU.8f SODWMONGCALMFOMMODMOK NOM SFTOMMaANA eee ON erm Tore - pang omtent extous pnp - tial SOCMMOMONNAM KETO MOMMKKARANDAM DEEN MMF NNO PS HMA NORM HOMM onto -_ ontotot=otor -_ SR OPMSOL OR SDK EMNAXOSTMMOOMAOMOO baa aa ee eeeeDANLOMOOAMNMEMO-DAMMMMNDOMOAONnoO-DEMOMFNAUNMNEMNAMMEMNAMONMMNDOWOD™OODDototMet ot mom Ont8etotontontot=8wh8 mtonotomototPOOOOOO OOOO OL LER Ame ODDOOOD more ontokO84otosotot. 1182.65MAX.LAKE LEVEL DURING ENTIRE PERIOD (FT)= 407 BRADLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWARD,MIN.SPILL) CASE | SUMMARY FOR MONTHLY MIN.LAKE LEVEL (FT) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG SEPTYEAR FEMNUMAY-DDOPAIMDEHMMUMOMOOAM OOwheled dd a a ee eeeeeeeeeeee.ANOANOWMOHHMVUM DM HKHFMMMAOAUAOIMOMOOHQ wens FADES NAMM AOMAMEBDONNUMEDOOCO-OVO ees eee ee . ee e ee e eee °°. eee ee @ ee CRM AIMNANDOMAINAMTDOMKROMe HOM DENK MAHOO DOHHMI MNURHODNOOEHROMToOOw tort ON OO HOOEtt ON OMI =ontototot oatoka8otot="ot: = NOONAN KAO TMMMOONOOTAMOMMORNNON °oseoeeeoee se eeeeeee©@eee.e ee cf] eee oe? WD AHROOMOOHKADMOKOLONNONMENAMOMECMNODADDDVDDDHODDDOOAMMOTRANSEMFRI =MBDOOO9BOOOMDODOMO etm otes otontotontetO38otAMDMIMOAOOPONOAGMAOANMOMODENMANOO-*see 8#¢ ee ee ehh eh hmhUcOOOhOH PH FeFewe owe eee 8@DONOOAGSOAOSSCOMOAGAGCAMRAVAMAMAYMowoNnFADDOE DOM DDD AD™ VDDRAOMOVONOUNMYmmOQooooooo0000o0o0o0o0oc or onhee] ontoeotome.MAK OAMAMOAOAMONADOSAOCOVDNCOHINOCObadly eoes#ee BOsKDAMAOWADOAROMAAQWRAOFH-MAaAmenoon FOAOBOMH DOH DMM DOHM MDE DHOOM AIVOoOmMmonmm smmeesesooooooosoooooo oadotontosodo=8ont - AOAKLMDAMNOANHOMAMAMAVDOMHMNUNOPFOAMCOD one 2p @#eese @#@@eo OO HoHeMOe Oh hehe oeeese Det OOO OOaeea BOA MOor aM MFOMDL LAOH ODLOADOMODKLAVENMOSTHIMEESFMWDWOODMOFNONOAOOAMMAAIMDEO""H=-HOW ov @ ee @ee oesee3e3or+eteeoeew#eeeeen 8@ eoe37eeNDMWMDFONOOHOIM DOHOMOMAAHADAPOOMO SO OFHMOO DDO KHDOVAtO (MAM ANNEMTONNSTHINDMOD"OMDONMCOD-DOANANMAIHODIMAmMo oe e@ eee ee ©@ ee ewe OeOhOhUlc hUcMCUHW US eevree8ef8fe8@ PX DANE FDADOMNUMMAOMAMIMONDAVNSNODWOMMMADSOHOOSANUAINDOMAUMMSNOONMTONMERON FOAPOKANOSCOVDAMOOKMHTOONeDeoeeeseseeneee@eeeeeeteee eeeo4eet e@eeese NOOO KHMOMEMMNANDDOTCAM "QOOAIMAMwOo PONANOANMNOMAONVNAMIEMMMOPTOMOMHOOWtotontotontotCD DMS 0rtrtttetotototontDAAOFTCOCTNMODMOPONWMOKMMNAGCDAMMNMNESeoeoeeeeeeeee et ete ese ee @ ew © oe pee @ew@@ BOON HMOM NF NUMROMDPTOMNNHM AONANDOaW PMOMNM CONN MHI AMIMNMONDEIEMOMOEOEH6O - oO pars wtetent AWTS HKMOMMOGOOMCTANMOLONMNOTMNHOCHMwo didn gta ee ee ee ee2 eoeoeeseeeeeeAGDOONOALMCDMNODAOHLAGCMHMOMNMANAPi MONON MMMMST ONAST NUM MOMMEOMO otot o=text o=tont tmntontwt =-ten waeFOFMNMONMMOVNDMDIMNDOAOMNTSmMNUMOMoeeee ee ewe ee ee ew we em we ele soe eee eeeEFMOAOMEMAIMOMMNVUMTOM AIAMONANMOOwoP Berens MMF MN NOMFEMMO NPDIDM OOPre °o oto ontext Be eh ae Bae OT HOR DAOmMeMOa AARAAAAAADAADAAARDAHAAAAHHAAIAHktntokondOkOdmdmdOdontOdmdOtOntUEOnt 1079.93MIN.LAKE LEVEL DURING ENTIRE PERIOD (FT)= =, BRAOLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWARD,MIN.SPILL) |CASE SUMMARY FOR MONTHLY AVERAGE SPILL FLOW (CFS) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG SEPTYEAR oeMOQOOCOSCOOCSCSEoCeooeoor GOfCcoomwo wo am rmBOOSOCOSSSOGCOCSCSOCOCOBOOCAMocCOwoOam @ - me -MOOOSOCSCOCSSSCSOOCCCoCCoCeCeCoorftoooo0ooeoev ese veee eee ee weewmwreeweteetrelhlllOe HP POPSS OOS SOS SSSCSOSCOsSCSCobdSOSSOSCCeoooooocoooeOoOCcoooooCoe.eSEOSCOSCSSSSOSCSCOCOCOCeOOCOCOCCOCOSEQECooooeooooNngeooooooeeocooocooeoeohannah dd dnaa hd ee ee eeSeeoeocooooeoeooooeeoocoeooooceoohah bah 1-[ 1Tf-T1-f-TTTT1-Y-1-¥-1 1-1-1-Y-1-] bd dh add aad Te, aoe eeSEooooeeooooooeocoocecoeooooceoec0oSeoooooeoosooeoooceoooeeeocooocecneahahaha] -l TtTtTT Flt TT 7-7-1 1-1-1 -1-1-1-)SCEOSOCSCSOCSCOSOOSCeCoeeoooeooooocoeoeha eae nd dad aad keeeeSSESSSSOSSCOSOSCOSCCOCSeCOCeOCCOOOCOCOSOeooooeeooeeeooooocoeoooocooeoeahah TatTT] -T-t-T 1 -F-f-T-Y -Y T-1-1 -1-1-1-1-1-1-}MOOSOSSCESSOOSSSEESSCCCOSCCCCCCOCOCCCODe ahahiLhTTT TTTt-7-fT f=7 f 1-1-1-1-1-]-1-1-) WWMOOO OOO COCO MEME MMmMmmm ODODOOA 12.22ANNUALAVERAGESPILL(CFS)= Ca, BRADLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWARD,MIN.SPILL) C ASS | SUMMARY FOR MONTHLY OPERATING HOURS SEPT TOTALoctNOVDECJANFEBMARAPRMAYJUNEJULYAUGYEAR MOOOSSGOSSSSCCOSOGOCOCCOMCOKHOORMOCNG0000otontontoutemt an SYEDAEDOLDAL)ALDALDALDALDALDALDALDALDEDAEDALDAEDOLDFPPO DP1UDEDPPOLD FPPePoMePOMePeMePePePePePePoPCUP MMMM OPFMAAOMm FANNIN NNNNNNNNONNOPNINMOTPEDALDLDLdLDALDALDALDAEDALDALDALDHEDALDALDSPOSDOSDPDLO ODAGOGOOOOGSCOOOGOOOC "OM OCVOOCOOFOOOVOODAAAHAAAAHOGOARAMAADROAAHAHRATAHARHAMOre rrrrrroerrrvrrerrrTrruTrorr errweCOOSOGNOASDBMG OCOCBDNMMOOSCCOCQCCOCO NNN HE OMOMNO NM MBO NNN ORRIN PP PPO OD19DPWPPO FO63PHPHPHPEPRPPP PPPPe FTTOO "DWDMOVWOOGONEMMMOOCeroersTCCwuvwe FEFOHMMAHAINKADSMMOTCNCCTCTCTrrTeCesEEK OON TONS COSHHMMMMmmm -M SOSSOAsKLGOOMOMOCTCONOMODCZOCCCOCCOODOOOCFNOOMOPOCONONCOCOKDCOODSCOOMMOMOIMM=2t MONA MMM OH MMOMMMMMMMME NNN NPN NNN MINIONspedfddndtindfddnd,4)findSadAnddeeddiedndond,>LikntLipa lalaioioioinioieion MMMMMONMAUMMMOMMMAMMM FH MMAMMAMaAMMMem OO DBOOODOOODOOCOCDOCOODOOCTCOCOCDOYMNF OIMOMF MMOOF MMAF MOOT OOAMNSOMOAMNEOME MOAIMOAMAMMOAMOMMAMOMAMA MMAMMMAOMANM baddadAapSaabtndAapRelaAapdapwpmppabpubapepeLIbaLaLaiwinininivirlri)PneePeRePePePePeMePePeeyPeFoePnPeEF)PrePeePenPePe,PenPePePnPePeMMAMMMOAMMAAMMAMMAMO=IMMMMAAMAMAMMNANNN ANNINN NNN samedyanakAneAaahidsSiddiedendSaadafaefads Lt adk tteMMOAMAMMMMMAMMAMMOMAMAMMMOMMMMMOAMMEDBDOOCSSSOSCSCOSSCOCCOCOCCCOCCOOOOCOOBDOOOOOOOCOOOQOOQCOCODDOOOHODOOCOOOOOMMOOAMMMNM MMMM MOAMAMMAMMMAMMOMMAMMAMMNAMwewrwrwrrvrereveverrorrerwreqrwverrerrsewrevwrwvrerwrwqewrrwrrrwrerwrwveorrerreebdiedBiaidBiddidfedeltltdaedee a ae edtan BS OO OSS BO NOT MOR DAOANM TOO DIDO OOOO OOOO ORM mmm MmmMmmm OODOOOOA meat 164486TOTALOPERATINGHOURSDURINGENTIREPERIOD= 7 of / BRADLEY PROJECT POWER STUDY (45%HOMER LOAD PLUS 7 MW AT SEWARD,MIN.SPILL) CASE | SUMMARY FOR MONTHLY ENERGY (MW-HRS) SEPT TOTALoctNOVDECJANFEBMARAPRMAYJUNEJULYAUGYEAR NADADADAAAAAAHAAHAAAMAMAMMAUAHMmODAGO OOOO COO OOOOOOOGHOOMODOO="OONDO PDDEDEMDFDFDCPDEVDCFDEDCFDCFDFDCFDCFDOFCFD.OFOFPROF)ODPePETEDPDIOETDoeoeteeeererevee emer ee wm cemhmlemhlUlc OCCOmhUlcOCHO POHhHO Oem He8le DO OOO DODO ODD ALVBMV OOTOOMO@DODDODDDDODVDHDDODDVDDOO"DOAMDD9MODODOMWOOODODOOOVOOVOOODOOCOOOOONHMHHWOOSOA0 DD DDDDD DD OD DODWDWDODVDVD "DDAWVWDOD"DVHI9O 0 DUM MAMMAMMAAMAMAAMMNMAMKHAMMDONMMOWOMoeeeeeneeeeree ete Oe wee wee we woo wee @eee¢#ve.SOOODWDOMFNGOOCOCOTOOMCOCCOCCGOOCCOCSCSDnker8FO OPWO mm CO MIMI NEN OMMAHMUNOO a4 MAMMA VUNAADADMAIMOMAMMMOMMOMMOMOMMEOFCCPCIMMOANMSECEEAUMNKSTeTevsqvwewseueeObOtndOrdordwdOtOntokOonhOosandnededSiehRdidfadndinedSindfinedRoadaedfinefinedJindfedfinedfinedfonrlfartndfelfantfanttehoaAAADAAAADAAAAHADAAHAAAHARARAAAHHMma -_ ao i=]Co@OODQDon DODDOODO®DSwrrrwrwrrrretroewrererrwvereerreurreCDwsomeANANNNNNNNNNINONINNNNNNNINNININONIINNN oee37@e#e#neevee#ee ees #@@ee@@SOoOoooooooooooocoeco0000OeQODQDODODODD DOOnDoaoaewdeeee2ey DAO MVM STMOKLDAQKNUMFMOOKDHAOA@NMENHWWMOODOOOOOOOOLLLL EMME MmMODODOODODODHPHAAAAHAAAAAAAADAAAAHAAANAAAHAAAHAAHm8Om8otOm8otot= 888OeOtntotOEOnoN8O88OSwdOn §3100.38403.19716.19716.18444.19716.25320.51243.43110.68390.88564.76724.MAXIMUM MINIMUM AVERAGE 17015.32600.31676.36900.7199.1880.1078.1384.4419.19716. 40688.22063.19716.19284.17412. 39277.21480. o4716301.21320.38897.398699.39276.45441.43160. 365459.ANNUAL AVERAGE ENERGY {Mw-hRS)- IFS BRADLEY LAKE PROJECT POWER STUDY (10 MW MIN.LOAD,WITH MINIMIZED SPILL) SN SUMMARY FOR MONTHLY AVERAGE LAKE LEVEL (FT) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG =SEPTYEAR OFMWOOOONMSMNAO MMOD CUDHtettotwemtey of. °ee ees e88@e ee 8 eo¢ oeseefe @8@@@*.©AOADDNVNOALHSMM MAADUMMONNOOAFTTONn PL FNM AINAUMNMOMSHINSHODMMDDSOMOO =o -_ oun MONS DNOND MH MODIMANSFSRMAOMAIMMOAaN Ld e oe50o+7#eee#ee8ege¢e#reeeeeeseeseeeseee#eeteeseFANON SM OFAPMMMNVNONMOMSTONE OAM Nw mtototom oe HO o=tot6. Chand moment ontmtontot =tot PNM MANE OM OMADHIDAIDMNOMKMOw!s ee @eoeeenwreeveeee#s#eoereeeseeetkteeee#es#esee@ MP MANO OAOMAMMItPOMOMMMV AIRMSESNO EK MODOAADDDROO OWDAWDMAMMNAHETMANNMMOS MMMM MOQOOOO MIM OOOO mO tm nentiateteat ARRON HKMAIMOSH MOAI MIMONOMOONMAOMRMO eeeeee e° ee°seeeoee ee°eeeo°eee°NDFEMMDOOCOCONOMAONOAMNOROERAmOHetMNDONDGDBDDODDODODDDDDDDONAAMONHHMMR="SOVCVGOCOSSOCSCOSSOMmGmm Qarntmt FAONSMOMQMMHMIHINVNOAHAO"-""-DOOMH"OM- Oe oeoeeernrevp ef 8@@@Fe @O eee ee Oe ehUcrOChUc OmhUchCh OCF ee DADO "GOONOOSOOMONOOCOTHANOMOONHAnes FNDOD DDD DDDVDAODDDODDAIMMOAtOMHsiMMFNAMMSOLMADOMOCONMOKLKMCONNER RAM eoe7ec3eoeeeeeeeeneme eee emo eo wean ee eo ees OMIODOOSDDBOVOOKMVAOMOCONCO="AMR2Oe MOFOHDODDDODADDDODVODWDDHF NNOFONMS otototodNAMM MANAHOMMOBDMONONOMONMEMEDOEDeoe5oreeeseseeereeeeeeeeeeee oe eseese#eMAFNDNOMADMMAOMNVOMOMDOANTMOH Atma BFOMNO DDO OWAWMArItDADVUAIMANMOMAMIN? mmm OmMOOmrmOQOMO-000 OM MOFONVNAIMUMOMMMOOCOHMONDO OM ee LJ.e eee eee#ee#eeee#e#s6 eoeveeee&#eekekeees#e8@ DDN CV AOAO NM HMO MMHMMOOD atm mamOOMKMOMADOHAAOVANONDODNUAUMMSFOONMONMHI MINIM OQO MMO MOM OMo 4 DSF MMOH NMS HIM OO MAO OSTSTOMOM atMMH Ld aha ee ee? eoeeee#MMMOFOMMODMMM MAAMOM AI ANUNOWMMOrMONONOAMINOFMONAINAMDAMNOPTERKOMEOO,apap auipepaebhdbd.-_ dapaniam cumhana aman. kalhanke korean tare tnoto=6w=4ondo=0ontodot NAAN MMOGDAMOOMOONMWOM™ STMBDHONKNHAMm oeoeteeeeeee ewe em eweemhlhOhOhOCOhlOCOOwmemOe BODHI MMF NVNOANO MMM ENVUMGMMMPFaIMODAOPONMHMIMOONMMAIMMAUMONDSTNOPTMEAOMEO-_ Onn tort - os BONDOMAIAND("=IMDOMOTMEMAOCKrOMAGHO- oe eeeo ees eo eee ew meme mee ehOmhlOCOCOlt SKI POOMNADSCOFTOHAIMOFOsINANMOeaAMeSNSean RN wst oMme wunwowresene - = =o -_ "onto - =OU0oto=4otod. - - os - - - MFM MOFCASFKMOMDMONKMADA(F*MNOAnmoom .e ee8 oe34eo+oeee#¢ oe ee eoees¢ eeees: seoeee¢ AM MPFMOMOM SIMO DFAMMMEKMEFDSFOMDKMOWNMND SENS MMM FMOMONANEMOARONE Mem =to t maton' Onn = =Aontoatotome,WMOO OOOO OOO OL LLM MMMM DOOVDOODDADAHADRAAAAAAAARAHAAAHAAAAARAAAARH 1123.75ANNUALAVERAGELAKELEVEL(FT)= aw BRADLEY LAKE PROJECT POWER STUDY (10 MW MIN.LOAD,WITH MINIMIZED SPILL) SUMMARY FOR MONTHLY MAX.LAKE LEVEL (FT) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG SEPTYEAR ontntototototKR DOFTNNOMINMBMNONM ANNO NMMANOM oe e cere eee eee wmewe ewe wwe ewww wee e NAIDOO FO MO MAIN MMMMEFMUAINUDAHAANNMOOW DO NM NNN tt IOS MNOS MOT NMOAMMM OO TOetokntekotetthohotI III = - CQMOMAAML OP COCOKLAAMNSFTEDAMMMDQEnAnma ee eoeeee#se eee eee @¢6e oso eet @eeeeeee MVNO MDMADNONAINSEDOWOM OM ANNMD DF MMM AHOADHN AMIMI NUNRHODNANMMONDOMMPOe SAMI MMM ONOOO MIMO TOMItO-MVIMOOOOOS0C0090S S000 Haein - PR FNMKMNAINENNNDIMIAINNOOAMANHOMO Ten1id a ee eeeeeeeeee eoeeeeeee eee NONMDOO"DOSONOMOCOMNOST mM EMANWMA MOM DDODDDDADDDODADDDOOMNOCfoOnMeMm==mOOOoooooooceoo0000-4o=0otext =OentontNOMOFAO"QOO™4ALCDODOL LOK OKRMMMEA eoeeeee ee wm ew wee wee le oe e©eoeeeeeeseee@ QOMOMOCOOON TONAL OCOOMRHHAMMAToSFONDODDAODADADODAOMI PNUMONMHKNMeS MM OOmMOOOMOOOKO=000+ - - MDO FOAMS HIMAMMMNODOOBDNOTAnNOKeEm hdiieddidin tha a ee eeeeee ee) ose ee ec@ ese ee @©@ DNDONMN VO FSENOMAKMONOMOMNMOMREMOSOCOMOOAN"DDO"AODHOmDODANANOMNMONNMON Sphaphand -Aaph- A - haphaph - lewd - Lemdandund, -Lemk- amereeeeepepplnarrai) ontotot = - - MOD DORKOAIMVDONOTMAIMOMNOABMMOMR|S *eeeeteseeeeeeeeeeee eoeeezvs#%ers#e#es#es#ee MDOWMDONANE AMLMAMMAOANANDAMOMOOETRAMOMONADMNOOANOND"DMAUMMNTROMeONn _ eo QaranOnor =o os MFM FOTO ODOOMFrOANAIMMOAOHM-ON eee enoeeoeeseseenereesee e*eeeeeeaeeee8s8 6sOFOHADENAMIANOCKMOMNDOOANEND-ANnorne- - -_ AOMNGOOAOMHDON MMOPKLANOAMNOMmHEMOMmW eee oe fe @##@@© ee @©@O ee ehh hthlUc lhl ee @eeeeDINMMFODLOHKVONMOM™DOPFOOMOMAGCNMTDeet MONS TNR OMAR mre otototoe = = COMOONNEMNNAMODOTNE SH DOMEONANNAAD Lid a es es @ eee ee 8e@SFrAAMMMONCDMOMMOTANMONMOMCANeanoeDRO MM MIM ENNNMNE AHIMA OMAR Sree mt- - oateet8otndokortemtod00otohnd =otoe = OFAN ENSCMOOTA"TMOMKHAONrA"OCO see ef ee @ ee ewe e@ oO Be ew ew eww ee oe e ee et@we ew@SAMODOMKAMOANAMAMMADTNTCONWMOAANOH-*DBOPNFNMIMEFMMMMO ST AHMOONDMMORMWMDSOtcatnkod8wtOhotomot ontnd8ototot mem otet DROSS SOS BAO NOT MOR DMOMNMT HO WMODOOOOOOCOWVC CREE ERA Reem DOOOOMa AAA LAAAIAAAAAAAAAAAAAD® 1162.65MAX.LAKE LEVEL DURING ENTIRE PERIOD (FT)= >46 BRADLEY LAKE PROJECT POWER STUDY (10 MW MIN.LOAD,WITH MINIMIZED SPILL) SUMMARY FOR MONTHLY MIN.LAKE LEVEL (FT) ocT NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG =SEPTYEAR MFO OMKTOM HKIMOMDMNUNOMMNONDINIAPFNNOS oe eo ee ee @ ee wmeh HhUhOhUcMFhUMCOMmChUCUCcOrhUhMhUhOOCUC OW eoee#eHe#ee#ee@¢ @ FOO FOO SIMA MKF ONAIODOMAMIMOOMW PeFNM IN II MOMSF MNOS HKOTNE AMO} == -- owt SDnt8otntwk8ot8odotohot =o - =eFTMONAODONLKLOMOMCTADADMAATAAOMAbn aid ak a ee eeoeSNNMMIAMAMDONOHAMIMEFDAODELOAMMOANNMEADF MMM HONDA AM MURAOMAAMMOWDMMTOE MMMM OASOO tH OKOnAO rato oxtexd AO PFPCONMIMO SOE COONOAIMKrAOWMPHOANA oe e©@seeoeeete3wew#eet ete eeeneteees oes @eoee7eve NOMOAGOSMCO"OAOKOCMOAMOMFOAWOMAN DMADANDDDD@OD AAGDODODaItvuAanoneumsBAMNNOAMAOSGAONOSAOMOAANVOBAMAGBD-MMA eoeetee#eeseee ee ee Pe wewe wee eo e@ ee @ ees ee @@FTMOOSMOOMOCOMOAGCAMAONOHMHMWBDOPCANnNNOFNUDDOLDOOEeMODODDDODVDEDK DODHMBVURAOonwdomm =O OS 90099000000090000010 HattOSmttotMAKHOAAHWAMMNOONOCSCOCMOTCOMNAADMMA ee eneesete ete eee ee@BO Oe ee eoeeeeeesee 8@FOAOAMAGAAMAMOOMOCOCAMOPCOKODAAMMNOFUE DOEKKLDKLMEDODVDODO™DOMUOCOMNDOMM&FMOMNAONFOAMADO"OCMOCOM-AMwMaTen eec35naoeeteeeeeeeseees e*eseeneeecssceseeeeeses NONODAO"GOOAANOMOMAOMMHDErAEMaAanN MOMNDHOOM™- DOOD ODAD™DOOMANMGCOneEMNOMOLOCO"OOMAATBODOMLOLMMMMMEA e#e3oeeeeeeeneeeeneeee os @eeneteteeeveSOAOMOOCOCONTANALOCOCCMRHAMMMNOCTOOLFANDODDMNODOMMDODAMDHK TNUMOW MAM|S MAO O19 99 HO OO FO HDOOO00wtoatob0nd00ontodotot MDOT DOOMMAIMBLOMNUNADMAOKNDOEANAGE™ oe ee #@@se eese eeee @8@e@ @@@ eeeesees#k#h fe@DBNDONLANMSTNUNOMAINANAMOMAMKOCANMMOSEODWOOMMDBDDOM(AGD(OMhOKRNAMMMONNMOMWtt 88SDS0ED6S0808028C8 S0880doat0008wdwudondodemtonto=xtext ototextMNIDMKKDOMOIMMDONVNOCTAAMOMNOANGOAIM|Seoecsoe#eeseeteeeeenexeeteeee oe op eee es ewe @@&@MDOMOONUNNSAM MAMMAIMANVAIDAMOMOOEMRPOMONDOMNDOANONDAILMANNOSE OMSOM \phen henhapanh.-.-aapnenhapaanh-Aaplantamh and,kee MENNO FOF DEODLOMEOONOMMODOCAKINeSoeeeseeeeenetseeteenweneveee soe wo ee eeeese eeOFMNADPFNAIANOKLAMNDGCOOANTHDO"ANONe MONO NOONNMIMONAIMANDMNNOCTTMOMSEOO =o SS 0okrtot8etwtobotomod APMNGOOOCOON A HOMF KANO MANOMAMmMtety oe eee e@ @@ ee@@@eoOew ewe Oe eoeere #@#e@e@ #8@8&@@ ROMMA OMAN Oe eI OND MOMMIM MONON MIONMOND SNE NDWEM OS ont8omot =o 8 08SS0880dwntokodhoototot toe = "eee eee eee eee ree weeeweese ewe enews FRAO MAIMNVNODMOMSSCPAUAUMOAIMMOAMCTHOS MMO MMNMAMNSNUNNONSHMANMNMS RMSE SRR omontot -_ MHSHttot montritePPLPtrtrdirSbtadendlchadtahpap=penatph3DMMOWOOOOOO CO-L ee Pm Mmmm OODOOODPAAAAAAAAMAAMAMNMAAMAMAMAAMNAAMROHekehantan) mon nOOtatkndotemtemtntodwm 1079.93MIN.LAKE LEVEL DURING ENTIRE PERIOD (FT)= £6 BRAOLEY LAKE PROJECT POWER STUDY (10 MW MIN.LOAD,WITH MINIMIZEO SPILL) Core 2 SUMMARY FOR MONTHLY AVERAGE SPILL FLOW (CFS) oct NOV DEC JAN FEB MAR APR MAY JUNE JULY AUG SEPTYEAR RBRSBOOSOSSSSSSOSCASCOSOGCOROCQOMOOO="0 MOVOSSOSOSESSSeoooCeOCoOoncoOoOMmrocowmowo Qn " MCOSSSSOHSEGESSSCOCDGOMOCODBDOOONSDhind aa ee @Q o aSVCoeoooooooeoooooooeoeooomococoe@ COP oooososooeesooescocomeco"eo " SOeeeeeoeooesceooscoeoeoeoooooooeeseSOoOooeooooeeeeeoooceeoooooeooceceohhaadn hdl -T-T T-T-f-T 1-7-7 -1-y-1-1-1-}-1-} hind aa a eeSooeooeoeoeoeooeeoooeoeoooooooCceBOOCESSSHSEGOQ9GCOOCCCOCOCOCeOOCOCODOSoooeeoeeeeoeooooooeoeeooooccceoeohen ana aana a a ee eeSOOSCSSOSSSSESeCECeooCooCaGooCooeooesSDSeooooooooeoeooeeoeooeooocooocesohaatlllTT-T-77-7-F1-fT-f-1 1-1-1 1-1-1)SOooooosceoooocooooeCCOCoCCoCCCOCDAead lTTT ttt 7-7-7 tf-1-1-1-11-1-1] 1-) oe eeSEooCooeoocesCooccooooeeoooocooocoPASC OCSSSCSCSOSOSOESSCSOSCoCooOoOOONCOOONM oe . eo eee oes ete ee ee OH Hh oO oO ome he eoeegs BASSO COO SOR BOT LHONDAOMNM THO MMDOOOOOOOOOOP RRR mM OODOOODOAARAAAHAAAAAARRAMAARMAMAMAAMAAMARAAADO88eedondontonto=8otemtondot otontemt - 8.70ANNUALAVERAGESPILL(CFS)= SHSPs BRADLEY LAKE PROJECT POWER STUDY (10 MW MIN.LOAD,WITH MINIMIZED SPILL) SUMMARY FOR MONTHLY OPERATING HOURS SEPT TOTALocTNOVDECJANFESMARAPRMAYJUNEJULYAUGYEAR KPDNOKM NEFOFTODDOD"AMBDMM=DODMODOOMOoOAMOM OOO DEM OMT MUNDO MAHAMO HMMM MD OA TFMOMMNAIMODANOMODADOO "OOO cod Mm COOOMMOCOMOMONMOCMMTOOCOOrOKOOCOSooo oQOoooqoooooooeooeoeeoeoecooooo baal Tala lal aa aaa tainininininio)PeeFeePePeePePeFeFoPOPwPePePePePePePHPePOMePePePePePePEPPEP FHODOHOODOODODVVDDVOICVOO"DOOFOOOoOH dbldet delduldeldeldeldetdeldelduyldulbetdeldtaitdlahidLL21LimMe2h3)Liat2) PED9LD E39 ALDLd9ODLdOLD0DSdO00OdOD1 DEDPePeePinePeeFeePePePeCadMePeePeePeePe£7)PeeGRPePenPenPePePeGPPePePePePeLehbpp PodePpppledpp madympdbPM bmLHe DELOLHLOLOL LD) L3LdSPLDWL£9ALDALDEHOLUSDLDADAFDALDALDEPAFD0D 0OOODDD aDSOCONDMOtMOMOM"MMQOOCOCCOCS2GOCCSCONVM O FNMA NM MOD NNOAININNNNNNON PM MMM OW OOOF HHO SOME MMMM Mmm mMmmP FTFAVUAOAOPBOLMFOMOMNKVeTewrsreqeqeuvwr"eFFM OOMOO KM AODeIerywowmnwsererveurwTeece POSEN MPN NNN INM MMe MMMM MMMM ALDLDLDLDLDALDPeHDALDHEDALDCFDAEDAL)OLDOEPCNSSDA DD WOO OOOCONOOOOPOOCONOTOOOOUWUKODOOOOOrer CrCManweereenere =< woewrreverwuwereSOMOCOMSOCOMOCOHMABAMBCOMOGONHOONUMAN AMINO ANN MNET MANNONNNMON ee CCC SCCSCC OCCT INS ever vewerres tetera ere Doe thal taDelo elalalslalsalalrWDOOWOCOCOOCOOODOCOCOOrOCOODDCOOOOOwererwrverrvwrrrqrrrwerrrse Ceowvrewrrerse Sdetdeldetdvtdeth Fietheldvid LbtoleIeItetinh aaa alalsyslatatats)OOOOCOCOOOQOCOCOOCOOCMOQCOCODOONOOOOwvrwrerrr rewererrrrerrtrrwerwwerwrerwrregMOOOSCGOCOOOOOSOCOBOCOCOCADGCOCOCCOOLebaldkdetdatduld SbtbtbtitbibIatpIhSbtetah wala iat at's)owewrwwererqeorvrerwrrw rrrrrweerererw wrrewesewrw rrwrreerrrrrrerrrrrewrerwwrwoeweewwrwrwverwrrerrrrerwrrwerwwrwrrrePF FoPOPPOPEPHPOFePoPPOPePePRPEP PLP PEP PEPE WWOOOOOOOOO OPH Lee KAKO OODOODOOAADADAAAAAADAARAADAAAAAMAMAAAMAAM 184179TOTALOPERATINGHOURSDURINGENTIREPERIOD= =(SUH-MW)ADYINT JOVYIAV TVANNY"CT9L9E IOVYIAV WAWINIW HNWIX Vi "2v@02 "TEHTZ "OZLEZ "SBSOY"WLLEY "EISED "LOSEE "OTEGE "STORE "O9SZZ "E9061 "62981 "OSTGE "LESTE "OLLZE "HLOLT "6EH% "WESNL "H9SBB "EEHZD "OTTED "EWZTS "OL96Z "EBHIZ "£6002 "EBHIZ "EBHIZ "HSSBE "E60ES "TL660 "O6TEZ "Lé26E"e1e 48 °L4S8T °8682"ever | ohemdhernd. end gmhamndamdemdamdameemelamal analavalendoakondondookond tone enDBOOOOCOOOVW OOOO OCKHWODOWOOOWOOKDOOUOO DD DD a hdeded EH OHAAAAAGHAUN DASEN&§ OC ODVNAMNAWNMHOWOOWAUSWN= OOO PMRW WAW0)WW WWW WWW)I)WWW WW GGGG)LdPNOOCOLOOMOWOOOOOOOOOWOOODWDNOOUNWMe NVNNVIONN SNNVMNNRNNNNMMNMNMNRNRNNWhdddadededaaadedddddadadddedST od aledceddedadadadadadeda dd ddSED RARIPIPIAINIAIAI NOPRI PORIPIAO PURIPOPRSORO ROPRORO PROPORAIRODwtotutetetetetetetutetuteteteteteteteotetetetetetetetes;sbedendand 0one 2ome - =" CBOOOCOOUOOOOWOOO DOOWKOKOWKO OOOH OCOOMSOGOOGOCOOSSCGDCOGOOCOCOOOCOOCCOOOOaRRVRINIAINNIPINIAIND = OMNI RRR RR RRPRIPORD oeowe momO PatGasdGnadGandGadGedQuudQuadGantGrdPendGudPPPDHHDLHDHOAHLSSHAHASAAAAADAADBDDDODDOODO 10OODBOTSDODBDODOODWOW WWW WW WW WWW WWW WWW WWW WW be a ernr22ieies MP PIMPOPOPI ADAI PPD RPRMAMYIDANIADPOPRIPOPOROPO NOPD OnnopxunQuadosPAD - OmdGamepreQuadGaGmgeet 22222222 2H2D2LLDHDHDHAAADSHAADSAADBOOOO000DGH02O202O222O2OO22OODO0BW WWW WW WW WWD WWWWWWWWWOWW WOW WO bd ee oree eri AdCdad9dRDODOdGdIOWIWW WIENGdGdGG °€ *€ "€ °€ "€ "€2H22HDADHDHAMHIWHHSSAAWINWWWHSDADWWI WW WWWIWIWWI WOWIADWW110DO GG -= DON DES DWAAAIADwadpeeaeset2DBODDVNDOODDON@ WVWWODOONDBDODOOOBDOPDADARMAAAADAAWADAMAAHWAHAAAAANBOOS OWOODDOOHO2ODOOOO2QOOO@DOOwBOODOWDDDDDHDOGN®2OO2DLODODOO@ONoeeeseee eee eo ewew wo eoeeo#e3see#eeeef 8@@@ WwwWwowwDVDadadrdhdedGdGGGdGdGdGdGadGaoGadGadGddGGdGdGdWOOOOH SOOWOOOOOOODOOHNWNOOOOHOOO-atfiomefadpatNDCP)ba=0omeCadtedmtGtOmeSomeGaPudPenSmadGemsfefsGedQedGdGenetGoudfensedRMPBMAAVWAMNO AMAA MOOG} SMH OCOOSHHSOOSOBOOSOOCOSCCSCOCOSCOCOSBOOCSDOORba eeaierSrSriririeeiia ns BOVNN CON HH NBOORONSAOAWOMWOANOoe @ e8e Ame a3nnt =AWW UdV uvH 934 NVC 330 AON 130 UVIAonyW10l1435 (SYUH-MW)ADYINI ATHLNOW YOJ AYVWHNS (V11dS GIZIWINIW H1IM'QVOT "NIW AW OT)AGNLS Y3MOd 193C0Nd 3XV7 AZTOVUE vAsho CALULULAIION SHEET CALCULATION IDENTIFICATION NUMBER J.0.OR W.O.NO.|DIVISION &GROUP CALCULATION NO.[OPTIONAL TASK CODE PAGE_ [Coac BS [stSs;Dus Rothe Fellow hearers,The pvourma wacall"|Adup Jer eT Yan dows,{las Waa Viol Used : Ox 4 Heat Wn year,Th orn BAX ow aly 12 wit WSL 4¥&.128 & DO will Rowe Se Kis She Bary Qruod on Ox \,:X\,18%|nneded21@Threwesom\wpak Hk Woda -Machne, " _qPrdwotaxUpperBradlesBaan ;Trem she ling Siam forenait woral fors|2 Comedie moohs.Ke Gil Orn "Re pl Gm rR Swwwaceas OU TheAessmuriyBorage.amch watts woe alts F- Weak Aho OTT iey pots dimond,the reuft SAB op er Oitv2.vy,We Dou?Varin Sgrane of€@NOWHekweHHnnNyNHNNYReNYHYNH5Feelelllloyfmwe®FweNYLOOoBNHOwewNYLEuvewwewwwwnooONMHOHewNHHeOoooa>uwNwhedaoaw@ 57°79 S$ VALLULAIIOUN OMoeecT CALCULATION IDENTIFICATION NUMBER J.0.OR W.O.NO. face= DIVISION &GROUP \D> CALCULATION NO.OPTIONAL TASK CODE PAGE _ CPySsSm TOTAL,LAKE INFUW (MONTHLY MEAN) \W33\S ISIS (DAAG S223 DLoG.Y 110.7 R48 T04 SQ.2 S13 048.3 Qqo,2. LOWER BRADLEY CMONTHLY wean ) 933.8 [bart &Q.0 6s.l 64,6 She QO,2 10.4 (1X3 ai 16.| (98.9 J\VI TW ™ Y3 °/G2 Cone 3 BRADLEY LAKE PROJECT -LONG FORECAST RUN (NO MIN SPILL),DATE:7/12/91 SUMMARY FOR MONTHLY AVERAGE LAKE LEVEL (FT) 1AA2.»>[<14a\ MAR APR MAY sun |JULY AUG SEPT oct wov DECtJANFEB 1 1959.0 1465.7 1939.7 1132.2 1129.8 1118.31933.2 1166.9 1158.6 1161.3 1156.9 1155.4 BRADLEY LAKE PROJECT -LONG FORECAST RUW (WO WIN SPILL)DATE:7/12/91 SUMMARY FOR MONTHLY MAX.LAKE LEVEL (FT) t JAM FEB MAR APR MAY JUNE JULY AUG =SEPT oct wOv bec 1 1155.6 1168.5 1162.9 1136.6 1127.9 1121.21938-3 1955.0 1962.3 1162.2 1160.4 1157.5 Max?|1GA.> BRADLEY LAKE PROJECT -LONG FORECAST RUM (NO MEN SPILL),DATES 7/12/91 SUMMARY FOR MONTHLY MIN.LAKE LEVEL CFT) !JAN FEB MAR APR MAY JUNE JULY AUG SEPT oct wov DEC .e 1 1468.6 1962.8 1936.5 1927.7 1195.0 1115.39128.0 1138.1 1156.8 1160.6 1157.4 1153.3 Mine: BRADLEY LAKE PROJECT -LONG FORECAST RUN (WO MIN SPELL),DATE:7/12/91 SUMMARY FOR MONTHLY ENERGY (PAI-HRS) !JAN FES MAR APR MAY JUNE §=JULY AUG =SEPT oct ov OEC TOTAL 121483.20097,21683.29670.51263.43110.24960.39153.39150.39277.23190.21483.411 VIO [lIs.0 ./\'Sper:ad a.AIC ER Ime or worf POWER TECHNOLOGEES.,INC.ONE SIERRAGATE PLAZA SUITE 3408 ROSEVILLE.CA 95678 916 783-3566 TELEFAX 916 783-2086 TELEX 145496 June 13,1991 7 as cs> Mr.Afzal Khan Alaska Energy Authority me P.O.Box 190869 TUS "pHOY eco? Anchorage,AK 99519 Jee!micesTiomt OIF FP BNKW Are C2tns -CMF Levees ar Wee 2 HEA. Dear Afzal: Re:Kenai Import Study We have completed the subject study which was outlined in Amendment #1 of the Load Shedding Studies Contract.The scope for this study was given in my March 7,1991 fax to you.This study identifies the maximum Kenai imports which can be accommodated in the future when only Bradley Lake hydro generation is on-line in the Kenai.The maximum Kenai imports with Bradley generation are established such that they yield the same level of Kenai load shedding,following resource deficiencies in the Kenai,as would be expected for the same system situation when CT generation is on-line in the Kenai. This study analyzed system response under historical Kenai operating conditions as outlined in the appendix to the minutes of the April 3,1991 TCS Meeting.In all,nine historical load/generation scenarios were outlined,and they represent various Kenai import levels and Kenai generation dispatches.Power flow models for these nine load/generation scenarios were developed from the model recently used for the August 29,1990 load shedding study. In addition,nine power flow models were developed which represented the same Kenai import level,but with Bradley Lake generation replacing all Kenai CT generation.Thus in total,18 base case power flow models were created for this study.The power flow diagrams for these 18 cases are attached. With the base case models developed,we ran dynamic simulations which represented a resource deficiency in the Kenai system.For all but the Summer Case 2,this deficiency was created by isolating the Kenai from the remainder of the Railbelt system by outage of the Daves Creek-University 115 kV line.For the Summer Case 2 (Kenai already isolated),the Kenai generator with the largest output was tripped.In both cases,the outage was modeled as occurring without the application of a fault. CORPORATE OFFICES ©1482 ERIE BOULEVARD ©PO BOX 1058 ©SCHENECTADY,NY 12301-1058 ©518 3741220 --"\pr- Page 2 Mr.Afzal Khan June 13,1991 All dynamic simulations were run for 20 seconds following the resource deficiency in the Kenai.For each of the 18 base cases,dynamic simulations were run both with and without any load shedding relays in service in the Kenai.Thus in total,36 dynamic simulations were run for the base case conditions.The results for the base case dynamic simulationsare attached and are ahead of the colored page separator.These results include a plot of the Kenai frequency and voltage as measured at the Soldotna 115 kV bus.For the cases where load shedding relays are in service,a listing of the load shedding relay response is also included. Summary of Base Case Results The simulations without any Kenai load shedding relays in service were run only for comparative purposes.This is not an expected or recommended operating condition.As can be observed from the results,load shedding is necessary for the "survival”of the Kenai following significant resource deficiencies.This is always the case when only hydro generation is on-line in the Kenai.Where CT generation is on-line in the Kenai,there are a few situations where the Kenai frequency will stabilize at some reasonable level below 60 Hz due only to CT governor response (see Summer Case 2 &3,Winter Case 3,and Spring Case 3).However,as can be seen for Summer Case 3 and Spring Case 3,operation at this stabilized frequency would be possible only for 60-90 seconds before underfrequency relays trip the CT units. The simulations with the Kenai load shedding relays in service are best summarized by the following table rather than a detailed case by case discussion.The Kenai load shedding relays provide for 10 discrete load shedding events.Thus,this table shows the number of load shedding events which occur for each case and the resulting Kenai frequency 20 seconds after the resource deficiency.These values are shown for both the historical situations with CT generation and the same Kenai load/import condition with Bradley generation replacing all of the Kenai CT generation. --"\r> Page 3 . absMr.Afzal Khan ze srege tJune13,1991 ail "¢ Summary of Cases With Kenai Load Shedding Relays In Service __With CT Gen _With Bradley #Load Final #Load Final Shed Freq Shed Freq Case -Events (Hz)Events (Hz). Summer 1 5 59.3 10 60.1 Summer 2 2 59.3 5 60.4 Summer 3 5 59.7 10 60.2 Winter 1 5 59.6 10 60.2 ¥Winter 2 10 60.7 10 60.3 Winter 3 2 59.3 10 60.3 X Spring 1 10 59.8 10 60.3 XSpring 2 10 60.6 10 60.2 'Spring 3 10 59.7 10 <56.0 For all the system conditions studied,it can be seen that load shedding occurs in the Kenai even for the cases where there is CT generation.However,when CT generation is on-line, load shedding can be limited to as few as two events.This is particularly the case when there are two or more CTs on-line in the Kenai or when the Kenai import is moderate.With Bradley generation on-line in place of the CTs,resource deficiencies of the size examined always result in 10 load shedding events (i.e.,loss of all shedable Kenai load),except for the case where the Kenai was initially isolated. With one exception,regardless of the Kenai generation dispatch,the present underfrequency load shedding in the Kenai is sufficient to arrest the frequency decay associated with significant resource deficiencies.For several cases,the load which is shed is slightly in excess of the amount which would actually need to be shed.This is particularly noticeable for the conditions with Bradley generation,as the frequency always recovers to above 60 Hz before being controlled by deflector action on Bradley.This situation is preferable to having insufficient amounts of load shedding as it assures acceptable frequency recovery. The one exception noted above was found for the Spring Case 3 with Bradley generation. This condition has only a single Bradley unit on-line at 10 MW output.This output level is approximately equal to the Kenai load which remains in this case following all load shedding. This level of generation is not large enough to cause the frequency to recover quickly after ---\p> Page 4 Mr.Afzal Khan June 13,1991 load shedding occurs.This does not imply,however,that single Bradley unit operation is precluded.Spring Cases 1 &2 likewise have only a single Bradley unit on-line,but in these cases,Bradley's output is around 18-19 MW.This output level is about twice the Kenai load which remains after load shedding.For these cases,the Kenai frequency recovers quickly after the third step of load shedding. Summary of Supplemental Case Results In reviewing and setting up the Kenai load shedding relay models for the dynamic simulations,it was discovered that the load shedding relay at Soldotna has a 14 cycle time delay.The time delays used on all other Kenai load shedding relays range from 5-7.5 cycles. The Soldotna relay is set to pick up as part of the first load shedding step used in the Kenai (59.0 Hz).This raised some question as to whether the Soldotna relay would shed load prior to the relays in the second step of load shedding (58.5 Hz)picking up. For the base case simulations with load shedding,it can be noted that the Soldotna relay with the 14-cycle time delay does shed load prior to the pick up of the second step of load shedding relays.However,in one case the time differential is only 6.5 cycles,and in others it is in the 11-13 cycle range.Such a small time differential gives concern as to whether the load shedding contribution at Soldotna can influence the system sufficiently enough before the second step of load shed relays pick up. To examine this concern,Cases SUM1A2X and SUM1B2X (Summer Case 1 with CT and Bradley generation,respectively)were run using a 5-cycle time delay on the Soldotna load shedding relay.These results are plotted along with the base case results for the same condition.As can be seen,the revised time delay on the Soldotna does not change the total load shedding for this case or the overall system frequency response.However,the time margin between the shedding of the Soldotna load and the pick up of the step-two relays increased from 11 cycles to 22 cycles.The pick up of the step-two load shedding relays was delayed by about 2 cycles following the resource deficiency compared to the base case condition. Although these results do not indicate any significant benefit from reducing the time delay on the Soldotna load shedding relay,the possibility exist that there could be situations where quicker load shedding at Soldotna could prevent the pick up of the step-two relays.However, since this examination did not show any significant differences,all remaining cases run as part of this study used the existing 14-cycle time delay on the Soldotna load shedding relay. This is considered to be a conservative assumption. --_-"\p- Page 5 Mr.Afzal Khan June 13,1991 For Summer Case 1 with Bradley generation on-line (note:this case has the same on-line generation as Summer Case 3),additional dynamic simulations were run with variation of the Kenai import.These cases were used to determine the maximum Kenai import for this situation which would yield the same level of load shedding (i.e.,5 events)as obtained for the base case with CT generation and a 28 MW Kenai import.The result is shown as Case SUM1B2B on the plot also showing Case SUM1A2 for comparison purposes.This case shows that with only Bradley On-line,load shedding in the Kenai can be limited to 5 events for loss of up to 22 MW of Kenai import.This is only a 6 MW reduction compared to when Bernice Lake Units 3 &4 are on-line in the Kenai. For Summer Case 2 (Kenai operating isolated)with Bradley generation on-line,a similar case variation was examined.For this case,however,the only option was to add CT generation along with Bradley and Cooper Lake.Thus,this case (Summer Case 2A)has Bernice Lake Unit 3 added at 5 MW with a corresponding reduction in Bradley Unit 1's initial output.The dynamics plot (Case SUM2B2A along with Case SUM2A2)and the load shedding relay response listing show that adding one CT holds load shedding in the Kenai to 2 events following loss of Bradley Unit 2 at 20 MW.This is the same load shedding response which occurs following the loss of Bernice Lake Unit 4 (21.4 MW)for the base case condition where all three Bernice Lake CTs are on-line.As can be seen in the plot,the Kenai frequency dips slightly lower than for the CT base case condition,but the final frequency is nearly the same. An import verification case was also run for the Winter Case 1 with Bradley generation on- line.The base case power flow model for this case is different from Summer Case 1 in that it has both Cooper Lake units on-line in addition to both Bradley units.This case,compared to Summer Case 1,identifies the effects of Cooper generation on permissible Kenai import levels.The results of this case,WIN1B2A,are shown on the attached plot along with the results of Case WIN1A2 for comparison.A load shedding relay response listing is also included.These show that the Kenai can withstand the loss of a 25 MW import without exceeding 5 load shedding events.This is the same number of load shedding events which occur for the Winter Case 1 base case condition with Bernice Lake Units 3 &4 on-line.Thus, running Bradley in place of two Kenai CTs results in an import reduction of about 11 MW in order to hold load shedding to the same level. The largest differential in load shedding events (2 versus 10)was found for Winter Case 3. This was expected since it compares the Kenai as a totally hydro system against a Kenai system with all four CTs on-line.An import verification case based on Winter Case 3 with Bradley generation was performed in order to identify the maximum Kenai import which could be lost and not exceed two load shedding events (the level achieved when four CTs were -"\p-- Page 6 Mr.Afzal Khan June 13,1991 on-line).The results are shown as Case WIN3B2A on a plot also containing Case WIN3A2 for comparison.The associated load shedding relay response listing is also shown.The results show that the system can only tolerate the loss of a 12 MW Kenai import if load shedding is to be limited to two events.This is a nearly a 26 MW import reduction from the base case where all four Kenai CTs are on-line. A second variation of Winter Case 3 was run to identify how much of the "lost”Kenai import capability could be regained by running one CT along with the Bradley units.The utilization of the Soldotna CT unit was selected for this case.The dynamic simulation results are shown as Case WIN3B2B,and are again plotted along with the results of Case WIN3A2 for comparison.As indicated by the attached load shedding relay response listing,only two load shedding events occur.The frequency for this case,however,drops slightly lower than for the situation where all four Kenai CTs are on-line.This case indicates that use of a single CT along with Bradley will result in Kenai imports only being limited by about 13.5 MW 'compared to the case when all four CTs are operated in the Kenai. Based on the above discussion,the following general guidelines are provided: With only the two Bradley Lake units on-line in the Kenai,Kenai imports should be lmmited to no more than 22 MW. °When both Cooper Lake and both Bradley Lake units are on-line,Kenai imports should be limited to no more than 25 MW. °When the Kenai must operate as an isolated system,one of the large Kenai CTs should be operated at some minimum level along with both Bradley units. °When Kenai imports greater than 25 MW are required,one or more of the large Kenai CTs along with both Cooper Lake and Bradley Lake units should be on-line. These guidelines are based on the objective of limiting the amount of load shedding when Bradley generation is on-line to that which previously would have been expected under historical system conditions using CT generation.However,these guidelines do not preclude operating the system under larger Kenai import conditions provided larger amounts of load shedding can be accepted following a resource deficiency in the Kenai. -\pr> Page 7 Mr.Afzal Khan June 13,1991 Observations The results from this study are generally as was expected.This study confirms that the Bradley Lake hydro generation is not as effective as the CTs in limiting the amount of load shedding which occurs following a resource deficiency in the Kenai.Using Bradley generation exclusively in place of the Kenai CTs can limit the Kenai import capability under some conditions in order to minimize possible load shedding.However,based on the past, historical situations examined,it is noted that the use of CT generation does not guarantee that load shedding will be limited to only a few events following a resource deficiency.Thus use of Bradley in place of the Kenai CT generation does not always restrict Kenai imports below past historical levels. The underfrequency load shedding presently installed in the Kenai is adequate to prevent total collapse of the Kenai system following resource deficiencies.This is true for any generation dispatch (i.e.,all hydro,all CTs,hydro/CT combination)given one limiting constraint.This constraint is that when the Kenai operates with only hydro generation (Bradley and/or Cooper)the total hydro generation output must be maintained such that it exceeds the non-shedable load in the Kenai.The exact margin by which the hydro generation output should exceed the non-shedable Kenai load was not specifically determined.However, a level equal to about two times the non-shedable load was shown to be adequate (see Spring Cases 1 &2 with Bradley generation). The 14-cycle time delay associated with the Soldotna underfrequency load shedding relay was shown not to be a problem for the conditions studied.However as noted previously,there may be situations where faster load shedding at Soldotna could prevent loss of load due to the second load shedding step.Unless there is some significant concern with over-tripping or relay mis-operation,it is suggested that the time delay on the Soldotna underfrequency load shedding relay be reduced to around 5-6 cycles.This will make this relay's time delay consistent with the time delay used on other load shedding relays in the Kenai.It will also assure that the maximum benefit will be derived from the shedding of the Soldotna load prior to other load being shed at the subsequent load shedding steps. The present Kenai load shedding scheme sheds about 16%,41%and 43%of the shedable load for the first,second and third load shedding steps,respectively.This distribution among the three load shedding steps provides generally favorable load shedding action when the Kenai system is dominated by CT generation.However,when the system is primarily a hydro based system,the load shedding performance appears less than optimum. --"\p- Page 8 Mr.Afzal Khan June 13,1991 This observation stems from examination of the load shedding which occurs for the base case conditions studied.Resource deficiencies on a hydro-based Kenai system tend to result in all shedable Kenai load being shed.For the hydro-based cases,this results in the frequency recovering above 61 Hz before settling back toward 60 Hz.This indicates that there is an excess of load shedding under the present load shedding scheme.Increasing the amount of load shed at the first step and decreasing the amount of load shed at the third step may result in better underfrequency control without the overshedding of load. This study did not examine the benefits of reallocating load shedding among the steps used in the Kenai.This could be an area requiring further study.However,the feasibility of conducting such studies is largely dependant on how the Kenai system is to be operated in the future.That is to say,will it operate predominately as a hydro-based system,or will CT generation continue to be the dominate generation resource in the Kenai?If the latter is the case,the present load shedding scheme appears acceptable and change may not be warranted. After you and the Railbelt utilities have had an opportunity to review this study,please advise if you have any questions.Also,please advise if you would like us to run any additional cases for this study or pursue other,related system studies. Sincerely,Dy John H.Doudna,P.E. Senior Engineer JHD: Enclosure ce:Sam Matthews -HEA Dave Burlingame -CEA Larry Hembree -AMLP Steve Haagenson -GVEA osDAVE SVS 906BERNICEBERNICESOLDOTNA HOPE2.2 9968 9990 99869 SOLDOTIG 0.0 49:9994 ithe ae Sie omted¢13.9 -13.ef .¢flo.o CT)a)'"<4.5 3.1 <$o.0 0.0001 OLpavecR|Sls 16.4 1.006 9986 ninLe212.2 Soup svs a2 Ole o s,+=-0§-0.0 &--.S|baal bd3.72 a”0.0 nw tog 20-2)0.0 -3 --[3-%"Zz oe go9.00.0 -yy Py 13.3 QRTZ CR4.5 <a -0.4 30.616.s°2 ¢8 998lee 1.000 SKI HILL =15.2 254-20 _7 =11.0 a4 -4.6 1.4H=207 be '1.027 LAWING SKI HILL &%'are:oRTZ CR YY 1.023-H 9993 -11.9s'bl- t Nia olewhoPrsheTESORO)gic 1.000 '69 rf he =ilsi ' T ' '1 1 i '''i coop LK PJS 1.023 '''9991 oto -11.9 '4 ----------__ i KASILor ©83 ' 1 74 7 SOLDOTNA t yw oN'_' i)e 'ad2:a i be''a0 aloi r t 1 es ' 'KASILOF '' 'Veweencnre ne anwn mas 1 tBEAVRTP)0.973 t 70 14.4 '<=>tofbed'Cd Od ' ' 8 ' 80 'BEAVR CR ' 1na1Nr)4ANCHPTTIL:' 75 tha i sm 'Rd Lam t-”' § ' ' t t i] t tbl' DIAM RDG =I;0.970 H9965tt 16.9 :tat fra)' &"19 \<2 '957)12.6 '25 4 i a t a ' FRITZ CR H BRAD LK 9997 i $00 §bmn wwn mena -95 --110-00.0 -1.3 . 0.3 aeOo @ eraES |nnn.Sm |6°P°)ao es 1.3 v§fee£°%.0.300.970 0.000<--17.0 0.0 SUMMER 1990.CASE 1.31.5MW ANCH EXPORT,28MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. THU,JUN O06 1991 15:47 7 KV:<kQ e178 @92n DAVE Svs BERNICE BERNICE SOLDOTNA 906 HOPE0.0 9988 ioe 9989 SOLDOT1G o.o}|_a9 0-0 14,7 ret o¢flo.o $994 0.0 'ns 5.2 3.8 "S $0.0 0.000 1 OfDave*cR =!SIS\0.0 1.007 9986 tft 2'0.0 24.5 SOLD Svs -2 et .- f-f2.0 s oe ee eG3.73 a®0.0 nw eee S|@Qi4 -}e--soee8 -Z *goo-80.0 -a s _ RTZ4.5 -«w1.5 3987 cr0.6116.5O%5eeeo66 -18.4f{-20.80.999 SKI HILL 1$.3 :: 23.3 a4 4.9 O.Sh-1.7 9996 1.035 LAWING 28.0 ORTZ CR 1.031999327.0 baal Lag]f-TtwlaoleTesorools'| 69 TIP ' ' ' ' °'coop LK Sig 1.031 we '9991 ol?27.0 2,025 ' --|+olen la ' wee,qe aie'i ]t=]Qo1 , '85 'KASILOF 4 es ey ' BEAVR TP,0.983 70 24.5 ="mle 80BEAVR CR ANCH PT @I;1,0217§me 5.6 Mim ole 1 DIAM RDG O],5 1,021 9965 ="25.9 wim %-misan209.7 ' zz 32.5 a BRAD LK 13.3 2S.14.5 "1.4 32)FRITZCR891.680ol-wluueOoOnw"aSUMMER 1990.CASE 1.31.5MW ANCH EXPORT,28MW KENAI IMPORT. BRADLEY LAKE 1 &2 ON-LINE. IFRI,JON 07 1991 14:20 KV:£69 ,£138 .8230 SUMMER 1990.CASE 1.31.5>8 ANCH EXPORT,28hw KENAI IMPORT. SRADLEY LAKE 1 &2 ON-LINE SUMMER 1990.CASE 1.31.S2@ ANCH EXPORT,200W KEMAI IMPORT. za BRADLEY LAXE 1 6 2 ON-LINE.zaTRIPOAVESCREEK-UNIVERS ITY 11SKV W/O FAULT.=bel TRIP DAVES CREZR-UNIVERSITY 1ISKV W/O FAULT.ned G)NO UNDERFREQUENCY LOAD SHEOOING ENABLED."=x WITR UNOERFREQUENCY LOAD SHEDDING ENABLED.4= FILZ:SUMIB1 .CAN a FILZ:SUMIB2.CUN om 22are)2a ao ZO zzaN8 =.3==g>2.2{v.3000 -_---7G.20008 ta -_--3.e088 <161.000 56.008 3 ---_34.008 {o im){q i I ||!q z x i i I J i E|3 3 ==6 bon |.: leHy . =|-7<-is \:;+=43= i :2 -_ +2 +-joe rea)-_,3 -x\© \2 fo,2ry/-_fa)is = :: =3 4s Lae +s Lo 3 g 3 "4 !!!! SUMMER 1990.CASE 1.31.5 ANCH EXPORT,28MW KENAI IMPORT.SUMMER 1990.CASE 1.31.5 ANCH EXPORT,28MW KENAI IMPORT.BERNICE LAKE 3 &4 ON-LINE.20a BERNICE LAXE 3 &4 ON-LINE.faTRIPDAVESCREEK-UNIVERSITY 115KV #/0 FAULT.=fa)TRIP DAVES CREZK-UNIVERSITY 115KV W/O FAULT.od balNOUNDERFREQUENCYLOADSHEODINGENABLED2=WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.a2=FILZ:SUM1Al1.CAN ”FILE:SOM1A2.CHN a zo 22232a =oO Hy =aN 8 =a.)=z ZegnfJOLROTMALISEVVouTAGE(Pu ge[h.3000 .7.2000 SS 8.20808 {Le) 1 = 163.000 o bersee sariESAS wad i I }i i i 4 5 is- 78 = e .7:3L.:="3 23 78 2 ¥ =is . ==s =« e 3eal3 - l !it !!it KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 1.31.5MW ANCH EXPORT,28MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =10.650 FREQ =58.997 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =10.650 FREQ =58.997 LODSEHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =10.733 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.817 73.00 PERCENT OF INITIAL LOAD SHED 2.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9690 FREQUENCY =58.782 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =10.883 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.967 47.00 PERCENT OF INITIAL LOAD SHED 3.2 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9792 FREQUENCY =58.628 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =11.150 FREQ =58.499 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =11.150 FREQ =58.499 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =11.150 FREQ =58.498 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =11.250 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =11.275 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =11.275 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.333 100.00 PERCENT OF INITIAL LOAD SHED ; 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =1.0154 FREQUENCY =58.406 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.358 100.00 PERCENT OF INITIAL LOAD SHED 3.8 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0048 FREQUENCY =58.433 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.358 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =1.0215 FREQUENCY =58.433 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 1.31.5MW ANCH EXPORT, BRADLEY LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 2.4 MW AND LODSHD AT BUS LODSHD AT BUS 3.1 MW AND LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 8.4 MW AND LODSHD AT BUS 3.7 MW AND LODSHD AT BUS 1.5 MW AND LODSHDAT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 28MW KENAI IMPORT. 83 STAGE 1 PICKUP TIMER STARTED AT TIME =10.675 FREQ =58.993 84 STAGE 1 PICKUP TIMER STARTED AT TIME =10.675 FREQ =58.993 84 STAGE 1 BREAKER TIMER STARTED AT TIME =10.758 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.842 73.00 PERCENT OF INITIAL LOAD SHED 83 STAGE 1 BREAKER TIMER STARTED AT TIME =10.908 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.992 47.00 PERCENT OF INITIAL LOAD SHED 0.5 MVAR (NOMINAL)SHED.VOLT =0.8919 FREQUENCY =58.781 0.7 MVAR (NOMINAL)SHED.VOLT =0.9017 FREQUENCY =58.606 87 STAGE 1 PICKUP TIMER STARTED AT TIME =11.100 FREQ =58.496 88 STAGE 1 PICKUP TIMER STARTED AT TIME =11.100 FREQ =58.496 691 STAGE 1 PICKUP TIMER STARTED AT TIME =11.100 FREQ =58.499 691 STAGE 1 BREAKER TIMER STARTED AT TIME =11.200 87 STAGE 1 BREAKER TIMER STARTED AT TIME =11.225 88 STAGE 1 BREAKER TIMER STARTED AT TIME =11.225 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.283 100.00 PERCENT OF INITIAL LOAD SHED 1.9 MVAR (NOMINAL)SHED.VOLT =0.9342 FREQUENCY = 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.308 100.00 PERCENT OF INITIAL LOAD SHED 0.7 MVAR (NOMINAL)SHED.VOLT =0.9469 FREQUENCY = 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.308 27.00 PERCENT OF INITIAL LOAD SHED 76 STAGE 1 PICKUP TIMER STARTED AT 84 STAGE 2 PICKUP TIMER STARTED AT 81 STAGE 1 PICKUP TIMER STARTED AT 85 STAGE 1 PICKUP TIMER STARTED AT 86 STAGE 1 PICKUP TIMER STARTED AT 84 STAGE 2 BREAKER TIMER STARTED 76 STAGE 1 BREAKER TIMER STARTED 86 STAGE 1 BREAKER TIMER STARTED 85 STAGE 1 BREAKER TIMER STARTED TIME = TIME = TIME TIME TIME 0.3 MVAR (NOMINAL)SHED.VOLT =0.9468 FREQUENCY = 11.625 FREQ = 11.633 FREQ 11.642 FREQ 11.642 FREQ 11.642 FREQ = AT TIME =11.717 AT TIME =11.725 AT TIME =11.725 AT TIME =11.733 58.313 58.304 58.304 58.199 58.200 58.199 58.198 58.199 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =11.767 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =11.800 100.00 PERCENT OF INITIAL LOAD SHED 3.3 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0378 FREQUENCY =58.144- LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.808 56.00 PERCENT OF INITIAL LOAD SHED 3.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0411 FREQUENCY =58.144 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.808 100.00 PERCENT OF INITIAL LOAD SHED ' 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0467 FREQUENCY =58.140 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.817 100.00 PERCENTOF INITIAL LOAD SHED2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0567 FREQUENCY =58.140 LODSED AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.850 100.00 PERCENT OF INITIAL LOAD SHED 6.1 MW AND 1.8 MVAR (NOMINAL)SHED.VOLT =1.0694 FREQUENCY =58.157 BERNICE _BERNICE SOLDOTNA 996 wore 1.4 9988 f°".9989 SOLDOT1G 0.0 49 2.0 |g 25.4 -25.21 ¢flo.o oo Se"<=3.1 2.2 "Ss .0 0.000 1 ' pavesecR |ft 24.3 1.021 9986 = 1.8 714.6 SOLD SVS a .0.0 98 &rls ; °body }--§-.oO -O ;°o who1286§a™0.0 gy g---feg 20-2)0.24.3 3.0%-Z ge 600.0 1.1 w <°o .3 r=) 13.6 QRTZ CR4.5 a -0.70-66.42 ¢&9967TIRee 1.018 SKI HILL 2.8 2.87.1 "12.5 a4 =4.7 0.6H-1.8 n i 1.027 LAWING SKI HILL&'26.21981'ORTZ cr VEY 1.023 =H 9993 14.3 -.t on ao le ”'wlio lo TESORO)lS 1.018 ' 69 TIT i2.5 ' n ' 1 ' 1 i 1 é 'a Are ''coop LK yjJg 1.025va"1 'ali a13.71.045 '©'744.3 !.t KASItor ©'iwIomi'74 t i]Pralanwle'-|} '.t aqd)2 ain ais'\ao alo 1 t 1 t 1 1 '' ee ae ' ''BEAVR TP,0.981 t 70 17.5 ' mo \ale ' t 4 a go 'BEAVR CR ' ! o ' te tANCHPTZIUs0.988 ' 7 on -19.5 '=e tainof=' ”1 t | i] i] 1 1 ' ' DIAM ROG Ol:0.981 H9965vt-20.0 4Coalfa)( %-=10 'fe 302-5)''23 o2.6 a o iea4 t t FRITZ CR 'BRAD LK 9997 }$00 an |eee See (oF0.0 FRITZCR89iqaudhoaabaluluswits0.982 -20.1 [SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. 3 &4 AND COOPER LAKE 1 &2 ON-LINE. 16:00 BERNICE LAKE 2, THU,JUN 06 1991 wer.wen wana mannan SAVE SVS BERNICE BERNICE SOLDOTNA 9e6 HOPE 0.9 9988 9990 9989 SOLDOT1G 0.0 L =3 - 490.0 |as "14.6 14.7 9 floc yy?"0.0 ro"< S.2 3.8 "Ss 0.0 0.000 1 ' DAVE ,49.0 1.005 9986 9.0 22.2 SOLD Svs a ° «0,0 98 «=elo wilco S.a +-0§-1858 or ee3.785 °ne : 0.0 3-3-0 "2 gu 308.00.0 -ai FE 2.8 ORTZ CRs+6.125608 Thea 9987 12h g 0.997 SKI HILL -2.7 2.87.1 21.0 a4 4.8 O.7-1.8 -20.8 9996 -0.9 1.026 LAWING 016 1.016 23.6 <3 23.3 oRrtz cr "XY 1.022 9993 25.5 ted Lat d aw we sotpotna 'ZY 0.996 wis silo TESORO alc 0.996 9992 22.7 169rt421.0 ” 1 e- El ' ' 'coor LK sla 1.025 ww '999 SIP 26.1 4 --1.023 ' -10.9 '"jo ala RA"-we t a,1 PE pi\soo Qo f] '65 'KASILOF ' eeeeay ' BEAVR TP,0.980 70 22.3 me ole 60BEAVRCR f ] ANCH PT "1S 1,02578wele pon os By i a6 ANCH PT a) DIAM ROG "IQ 1.0279965ia24.6 mo &19me9.5)7 ES 382.5 oO a FRITZ CR BRAD LK 9997 sco 21.2 os 20.0 @)"0.0 OO<0.4 17.3 0.7 Son -18 6 18,8 S$20.1)en 1.3|/0.4 2.6 <0.4eo)3 0.301.029 1.035 e 25.2 27.4 SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. FRI,JUN 07 1991 14:20 KV:<s69 .€138 .@230 a SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED.SUPPER 1990.CASE 2.KENAI SYSTEM ISOLATED. SRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE.2 a BRADLEY LAKE 1 &2 AND COOPER LAKE 1 6 2 ON-LINE.ba aTAI?BRADLEY LAXE UNIT ¢2 #/O FAULT.=G3 TRIP BRADLEY LAKE a OatT ¢2 ¥/O FACLT.5 NO JNDZEAFREQUZENCY LOAD SHEDDING ENABLED.bed =WITH UNDERFREQUENCY LOAD SHEDDING ENABLES."= FILZ:SOM281.CHN on FILE:SUM2B82 .CAN in 22°a)-<z zzFe$a==2G)g>g2 -_-- 0.20608 i 6.so0ee FADLASOAALLAKYFAROESE(REL 36.008 a M4 .0ee |a Ty l ai i 1 q i if 1 ao J E|4 2 3 4s +\: }2 mezz{- +: a]78 |1s "|:'g \€&soe 4 s 4:"< |:: 2 3 ==\6 -" « 3 e_. |! SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED.SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. BERNICE LAKE 2,3 &4 AND COOPER LAKE 1 6 2 ON-LINE."oa BEANICE LAXE 2.3 6 4 AND COOPER LAKE 1 &2 ON-LINE."0TRIPBERNICELAKEUNIT@4W/O FAULT.bd a]TRIP BERNICE LAKE UNIT @4 W/O FAULT."WwNOUNDERFREQUENCYLOADSREDOINGENABLED."=WITH UNDERFREQUENCY LOAD SBZODING ENABLED.2xFILE:SUM2Al.CHN c)TILE:SUMZA2.CHN 7.) 22 z2me)39 en 24 =fo)z =a R os _w ZaguJOUROTMALISEVVOLTAGE(Py)ge --=0.meee i [2.3008 _---oO a ISLROTBA _LISEY SREQVEWCT (82)-_-_--oe o [62.008 -_- q 4 3 T q i |mt T E i i @)1 q }1 qT i ; |:|: "we =: |*|3 |ss La | {:: 4:-|z |:;i - is]id =| |g |aie yl 3|5 i PSg 9 z |= +:b= | : | |73 -|. {2 Lo F 3 |3 >z >) ||_l wal _!al -!!i l i I _t !of KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. BERNICE LAKE 2,3 &4 AND COOPER LAKE 1 &2 ON-LINE. TRIP BERNICE LAKE UNIT #4.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =11.025 FREQ =58.998 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =11.025 FREQ =58.998 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =11.108 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.192 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0149 FREQUENCY =58.935 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =11.258 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.342 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0235 FREQUENCY =58.911 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP BRADLEY LAKE UNIT #2.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.642 FREQ =58.997 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.642 FREQ =58.998 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.725 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.808 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9310 FREQUENCY =58.798 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.875 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.958 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9329 FREQUENCY =58.652 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =1.175 FREQ =$8.496 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =1.175 FREQ =58.496 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =1.175 FREQ =58.495 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.275 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.300 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.300 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.358 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9784 FREQUENCY =58.358 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.383 100.00 PERCENT OF INITIAL LOAD SHED 3.6 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9998 FREQUENCY =58.362 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.383 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW.AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9997 FREQUENCY =58.362 DAVE Svs 906 -"17.1 BERNICE BERNICE SOLDOTNA 18 9998 [°90 9989 sotporicOomx;14,8 14.7 'floc 7)”'"<=6.1 4.7 "e Yo.d 1,9387.3 -10.3 0.3 et SOLD Svs = 2B eof ie30 e +33.7 ”.a@ofeeTONKZ5 0.0 -a < 18.7 ORTZ CR4.5 «a 71.0 g0.616.197 go 9968 eeuo68 --17.81.003 SKI HILL 12.9 13.0H-17. ell.a4 5.2 1.64=-3.2 °'1.033 LAWING SKI HILL 2/°2.014 'W227981t0o-13.7 'ORTZ CR 4 1.028=p '9993 12.6 aly I a bad bad bY 0.987 H Ties oe TESORO gic 1.003 9992 14.4 ' 69 tt "11.3 ole we ale r J ela wl olen ' t i)1 t i 't ' t coop tx S12 1.028 a 2.9625 59g sis cia.1,029 ' ”-3p.0 '=43.1 wo a3KASILOF 'Se |SASTLOF SOLDOTNA :Ata ole ela 'o ' ':'bey aurennen meee een'a }-ee'\ojo lo 4 1 t '4 f]t i)4 be wwece wees ob wwe eens \''BEAVR TP,0.980 t 70 14.7 ' o|Fr Heles' ' ' ' 80 ' BEAVR CR ' ' w e aw ' ANCH PT SIU;' 75 hr ' =|2 : ol-1 ”' ' ' t t ' t ' i le ' DIAM RDG SO};0.981 '9965 nip "17.1 1 Np t &-_Cael bod 'ey rn '' Ss '2S Q2-4 ' So t ' ' FRITZ CR }BRAD LK 9997 1 500 'bwwewmccandl -S---110-00.0 -1.2 =0.3 r.4oo ee |NETS SEEN |h2PA*)<1)2s B3-2 9.0 l =°0.3Yo.981 0.000 ko SUMMER 1990.CASE 3.28MW ANCH EXPORT,24.6MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. THU,JUN 06 1991 16:11 ; KV:£69 .£138 .€230 TESORO 69 DIAMRG*5 KASILOF eeeee i] BEAVR TP;70 OAVE SVS 986 FRITZCR69fBERNICE BERNICE SOLDOTNA HOPE9968rrSOLDOTIG0.0 49 | os 14,3 3 loo 7)94 0.0 ame-§.1 <yo.o 0.000 1 1DAVESCROfSIS 2 1.022 6 ths 24 3 SOLD SvS oIim wlio96&elo sla0.0 raf --oS rm -.-”3.78 ;a"9§-]555 ne 2650.2)' 3.05 <FZ s"300-0”a s - ORTZ CR 6.198 6.8 9987Eee 13.0-17.81.004 SKI HILL 23.1 a4 0.92.3 9996 1.039 LAWING 27.4 oRT2 cr "SY 1.035 9993 26.5 ovr OI Naaysis 4 4 ' a 'COOP LK o|/2 1.035 'lo 26.5 -4 ' 'AA 1 1 se ' t ' 1 ' 1 ANCH PT ™% 75 GS + ' eoDIAMRDG"Il.1.025 9965 oft 25.9 ww - alo g a9 7T s 62.3 BRAD LK 500 14.1 $15.0 D)"2.3 <-2.3 13. =i 14,9 ok 14.0 T-3.4 ed -2.3 FRI, SUMMER 1990.CASE 3.28MW ANCH EXPORT, BRADLEY LAKE 1 &2 ON-LINE. JUN 07 1991 14:18 24.6MW KENAI IMPORT. KV:69 .8138 .6230 SUMMER 1990.CASE 3.28M ANCE EXPORT,24.000 KENAI IMPORT.SUOTR 1990.CASE 2.2G"ANCH EXPORT,24.6hW KEMAI IMPORT. BRADLEY LAKE :&2 ON-LINE.=BRADLEY LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY LI1SKV W/O PAULT.23 TRIP CAVES CREEX-OWIVERSITY 11SKV W/O FAULT.bd S NO UNDERFREQUENCY LOAD SHEDDING ENABLED.4 WITH UNOZAFREQUENCY LOAD SAEODING ENABLED.ss FILE:SUNIB1.Can a FILE:SUMIB2 .CEN a” =a =a a2<s s23a) Zz = sRo2* =a) z zw2>ae |2a-_---0.20006 er}---0.20600 <JOLOOTRA Lisky rarcupece saz).<sser4 a SET LKY FRCL -_---J -<36.000 F:_-_-_-_--a i a |I q T |if ]Bog a |]|U i J T 4 |3 {3F43 \-; \:}icaeOPF\-'\ \:\ \2 )78 a ed = +7 {*¥}*y+=yy +-]z 3 5 3 +"3NN- "Is 5 2 3 kLit!i l : SUMMER 1990.CASE 3.28MW ANCR EXPORT,24.6¢W KEWAI LMPORT.SUMMER 1990.CASE 3.20MW ANCE EXPORT,24.600 KENAI IMPORT. BERNICE iAKE 3 &4 ON-LINE.=o BERNICE LAKE 3 6 4 ON-LINE.zaTRIPDAVESCREEK-UNIVERSITY 11SKV W/O TADLT.20 TRIP OAVES CREEK-ONIVERSITY 115KV W/O FAULT. NO UNDERFAZQUENCY LOAD SHEDDING ENABLEO.22 MITR ONDERFREQUENCY LOAD SHEDDING ENABLED.ax FILE:SUMIAL.CHN ”FILE:SUMQA2.CAN a Sa za =<24°o ° 2A 2a z ==[eo]BN g =7.) gol |#5SOLOOTMALU9RVVOLTAGEipy?"pe GTPA LITE VOLTAGE LP?-_--=ar pa [iv3ees 1) JOLPOTRA LI3EV gRpoumTy cat){{ -_-_-_-e 36.080 ad [6.000 i i Y q |1 i ]q s | |3 j z3 |EL 23 8 ou a-s -om ]¥s+= 3 4:= -- 3 =3 s a ee \ KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 3.28MW ANCH EXPORT,24.6MW KENAI IMPORT. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT 83 STAGE 1 PICKUP TIMER STARTED AT TIME =10.750 FREQ =58.999 84 STAGE 1 PICKUP TIMER STARTED AT TIME =10.750 FREQ =58.999 84 STAGE 1 BREAKER TIMER STARTED AT TIME =10.833 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.917 73.00 PERCENT OF INITIAL LOAD SHED 2.3 MW AND 6&5 MVAR (NOMINAL)SHED.VOLT =0.9771 FREQUENCY =58.824 LODSHD AT BUS LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =10.983 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.067 47.00 PERCENT OF INITIAL LOAD SHED "LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 3.0 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9924 FREQUENCY =58.707 87 STAGE 1 PICKUP TIMER STARTED AT TIME =15.975 FREQ =58.499 88 STAGE 1 PICKUP TIMER STARTED AT TIME =15.975 FREQ =58.499 691 STAGE 1 PICKUP TIMER STARTED AT TIME =15.975 FREQ =58.499 LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =16.075 87 STAGE 1 BREAKER TIMER STARTED AT TIME =16.100 88 STAGE 1 BREAKER TIMER STARTED AT TIME =16.100 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =16.158 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =1.0259 FREQUENCY =58.456 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =16.183 100.00 PERCENT OF INITIAL LOAD SHED 3.5 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0239 FREQUENCY =58.466 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =16.183 27.00 PERCENT OF INITIAL LOAD SHED 1.4 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =1.0411 FREQUENCY =58.486 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 3.28MW ANCH EXPORT,24.6MW KENAI IMPORT. BRADLEY LAKE 1 &2 ON=LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =10.792 FREQ = LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =10.792 FREQ = LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =10.875 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.958 73.00 PERCENT OF INITIAL LOAD SHED 2.3 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.8943 FREQUENCY = -_ LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =11.025 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.108 47.00 PERCENT OF INITIAL LOAD SHED 3.0 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9065 FREQUENCY _LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =11.317 FREQ LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =11.317 FREQ = LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =11.317 FREQ = LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =11.417 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =11.442 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =11.442 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.500 100.00 PERCENT OF INITIAL LOAD SHED 8.3 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9473 FREQUENCY = LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.525 100.00 PERCENT OF INITIAL LOAD SHED 3.5 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9512 FREQUENCY = LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.525 27.00 PERCENT OF INITIAL LOAD SHED 1.4 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9512 FREQUENCY LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =12.267 FREQ = LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =12.267 FREQ LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =12.267 FREQ LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =12.267 FREQ LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =12.275 FREQ = LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =12.350 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =12.358 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =12.358 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =12.367 58.997 58.997 58.814 58.670 58.496 58.496 58.496 58.347 58.344 58.344 58.199 58.200 58.200 58.200 58.199 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =12.392 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =12.433 100.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0498 FREQUENCY =58.169 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =12.442 100.00 PERCENT OF INITIAL LOAD SHED 2.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0534 FREQUENCY =58.167 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =12.442 100.00 PERCENT OF INITIAL LOAD SHED : 2.0 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0568 FREQUENCY =58.16 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =12.450 56.00 PERCENT OP-INITIAL LOAD SHED 3.3 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0686 FREQUENCY =58.168 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =12.475 100.00 PERCENT OF INITIAL LOAD SHED 5.7 MW AND 1.7 MVAR (NOMINAL)SHED.VOLT =1.0798 FREQUENCY =58.185 BERNICE BERNICE SOLDOTNA Hore 26 9988 ("°°9989 SOLDOTIG 0.0 4 a.2.4 "3.4 .s__flo.e T 0.0 :v"<6.6 8.2 "Ss $0.0 0.000 1Daves?CR 1 oa"2.3 0.993 996 saben 7.9 -12.4 SOLD SVS os ° «0.0 98 br whem a°&b=-0§-Ot)o>Po i)S18 45.-.ye---feg edt9.9 de--)*°4o "2 ee 900.0 0.0 -Fy 3 ° 26.8 QORTZ CR7.9 wo ol 3.1 51.7 8S Oo efes 998 LTRS & 1.003 SKI HILL =29.9 30.5H-26.612.1 84 -1.4 O.3Haea ol 1,005 LAWING '-7,2SKIHILLRie'. 98 rt 'ortz cr "EY 1.010 Leo '9993 6.4ales'as Se 'alo wlealer -ond TESORO |:1.002 '' 65 nin -i2.' '4 1 t !i '' t 'ole t 1 coop LK s]™2.014 : \1 9991 min 35.7 4s 4 ad ' 4 'Hh i-=---_.KASILOF flew CT ea)'4 iy 'awaspt--r PS ay emma'i )'al tal 1 oe1HQiCin .'1.0912 ' '85 i] 'KASILOF 't 'laaatateieietaiate whakatehebatet 1 tBEAVRTP!0.939 ¢ 70 -13.5 ' ar ' an t t ' ' 80 ' BEAVR CR ' i) oe 4ole' ANCH PT Fla 0.930 'eS Say tombe' rim t ”' ' 1.' ' 4 ANCH PT ' ' t =|' DIAM RDG T]3 0,920 '9965 yt -17.3 i mim t Pr)"to 'Sey 312.7)'' 23 @ 4.0 ! "o 1 a i] t $ FRITZ CR \BRAD LK 9997 '0 ae |Sa Seen (oF0.0 "1,7 "0.4 [-4o 2 Ene |Pa ---2-2__J)an =$1.7 0.0 ne 0.49,920 0.000 <--17,0.0 [WINTER 1990.CASE 1.41MW ANCH EXPORT,36.1MW KENAI IMPORT. BERNICE LAKE 3 &4 AND COOPER 1 &2 ON-LINE.. THU,JUN 06 1991 16:49 _|&V:£69 ,£138 .6230 OAVE sVS 906BERNICEBERNICESOLDOTNA 5.0 9968 ["...9969 SOLDOTIG 0.90 te 3.0 s "21.5 zi.6f__.¢flo.o a"0-0 68.9 8.0 <Yo.0 0o.occ0 +:=DAVESCR |Sin 1. 0.0 0.976 9986 Tes 33.6 0.0 25.7 sgio svs «Se Oe «0.0 -win aoQbe-=Ld .fs28.¢0% §--fore ng--pepzo.)oof 3,freee rs es goo0.0 -i S 9.4 29 ae =3.2 99871.a8l/a.se°:remus:"s a -30.6R-26.69.960 SKI HILL 30.0 :: 23.8 a4 0.2 71,041.39 3)591.0625 28.0 9996 79.7 1.012 LAWING wh g992 0.992 2.6 27.3 ortz cr "ZY 2.015994JaDaebaralosotpotwaais TESORO |:9992 , 69 fa al 7 ain ' ij ' coop tk GI™1.019 oy '1.999 mic 34.2 1.033 ' -9.8 \83 »jo!SOLDOTNA A ele Sie e 1 'of i'ba'ojl ol1 Ly ' t ' Lewweeennaeoeeeewena 1 BEAVR TP,0.949 70 26.3 od Cdale 80 BEAVR CR ANCH PT 75 .1.007 26.2 S°wo an ' azo a FRITZ CR BRAD LK 9997 500 a.t S$12.5 @)7.7 "<6.0 2 14.4 5.3 [4 qf=4 -16,1 16,2 of 11,9 @)noc 1.7[-5.7 3.4 <6 Lro330.4%)013 1.0312=-26.7 28.5 WINTER 1990.CASE 1.41MW ANCH EXPORT,36.1MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. FRI.JUN 07 1991 14:%4 wer wen wee aman | J WINTER 1990.CASZ 1.¢iMW ANCE EXPORT,36.lmw KEWAI IMPORT.WINTER 1990.CASE 2.41MW ANCR EXPORT,36.leu XEMAI I0PORT.BRAOLEY LAKE 1 6 2 ANO COOPER 1 &2 ON-LINE.e&o BRADLEY LAKE 1 6 2 AND COOPER 1 &2 ON-LINE.esTRIPOAVESCREEK-UNIVERSITY 11SKV W/O FAULT.ares)TRIP DAVES CREEK-ONIVERSITY 1L1SKV W/O FAULT.cqNOUNDERFREQUENCYLOADSHEDOINGENABLEO.2=WITH UNOZERFREQUENCY LOAD SEEDOING ENABLED."=x FILE:WINLB1.CHN ”TILE:WIWLB2 CaN a sa 2aaaa8°oZaZR zzfo)z =Ra Rg z*722 L 2>22TiT300e-ae besee |a ST)a L.ee |sonar a Paria)2162.000 ----36.008 Ss 34.060 aqiIVYqTJ|i 1 J E a I q 4 q ||£{3 :=4s "ss iz 7 |"-- {3 z -+:|2ss| --a)z --\aa3- a eB |Pr j:8onzs}:/:€Lad /53 rey'Ss is=\2 +: =-_¢|=(°: Lo £ H 3-«"le L i !a il rq WINTER 1990.CASE 1.41¢W ANCH EXPORT,36.Lew KENAI IMPORT.:WINTER 1990.CASE 1.41MW ANCR EXPORT,36.1MW KENAL IMPORT.BERNICE LAKE 3 6 4 AND COOPER 1 &2 ON-LINE."a BERNICE LAKE 3 &4 AND COOPER 1 6 2 ON-LINE.eoTRIPDAVESCREZK-UNIVERSITY 115KV W/O FADLT.=a TRIP OAVES CREZEK-OWIVERSITY 11S5SKV W/O FAULT.2 wwNOUNDERFREQUENCYLOADSHEDDINGENABLED.s=x WITH UONDERFRZQUENCY LOAD SHEDDING ENABLED.s=FILE:WINLAL CEN a FILE:SINLA2 CaN "a 22 22ro)mx}i 22 :3 25RN5472)Ga geJOR2CONALIEVOLTAGEPut_Tivjo00 ao,0088 {i ETT)aed ( )}{6).000 Se.00e |o bemsse i i |S q i rs a -s = ° J +:- >-g e .2?3 :vyLObf=-_- \ =a -VN 28 8=ait =PS 4 ¥ is &=Le +:ben :23 =4: k =+s om - z |3ss é Ne !1 L j *j 4 !a a =iZ og KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 1.41MW ANCH EXPORT,36.1MW KENAI IMPORT. BERNICE LAKE 3 &4 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ =58.990 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ =58.989 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.642 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.725 73.00 PERCENT OF INITIAL LOAD SHED 3.2 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0012 FREQUENCY =58.720 LODSHD AT BUS LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.792 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.875 47.00 PERCENT OF INITIAL LOAD SHED LODSHD AT BUS LODSHD AT BUS 4.1 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =1.0132 FREQUENCY =58.523 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.908 FREQ =58.500 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.917 FREQ =58.492 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.917 FREQ =58.497LODSHDATBUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.017 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.033 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.042 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.100 100.00 PERCENT OF INITIAL LOAD SHED 11.4 MW AND 2.5 MVAR (NOMINAL)SHED.VOLT =1.0358 FREQUENCY =58.340 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.117 100.00 PERCENT OF INITIAL LOAD SHED 5.3 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =0.9640 FREQUENCY =58.350 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.125 27.00 PERCENT OF INITIAL LOAD SHED 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0430 FREQUENCY =58.364 LODSHD LODSHD LODSHD LODSHD KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 1.41MW ANCH EXPORT,36.1MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. AT BUS AT BUS AT BUS AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER STARTED 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = AT TIME =0.675 0.758 73.00 PERCENT OF INITIAL LOAD SHED 3.2 MW AND LODSHD AT BUS LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME = 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 47.00 PERCENT OF INITIAL LOAD SHED 100.00 PERCENT OF INITIAL LOAD SHED 11.5 MW AND LODSHD 100. AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 00 PERCENT OF INITIAL LOAD SHED 0.825 0.908 1.158 1.183 0.592 FREQ = 0.592 FREQ = 0.6 MVAR (NOMINAL)SHED.VOLT =0.9172 FREQUENCY = 4.1 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9281 FREQUENCY = .LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.975 FREQ LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.975 FREQ LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.975 FREQ LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.075 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.100 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.100 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 2.6 MVAR (NOMINAL)SHED.VOLT =0.9561 FREQUENCY = 4.8 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9641 FREQUENCY = LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.183 27.00 PERCENT OF INITIAL LOAD SHED " 1.9 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =0.9686 FREQUENCY = LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =1.542 FREQ LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =1.542 FREQ LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =1.550 FREQ LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =1.550 FREQ LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =1.558 FREQ LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =1.625 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =1.633 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =1.642 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =1.642 58.994 58.993 58.754 58.564 58.494 58.495 58.497 58.301 58.294 58.294 58.199 58.200 58.199 58.200 58.198 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =1.683 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =1.708 100.00 PERCENT OF INITIAL LOAD SHED 4.3 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0857 FREQUENCY =58.152 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.717 100.00 PERCENT OF INITIAL LOAD SHED 2.7 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0831 FREQUENCY =58.149 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.725 56.00 PERCENT OF INITIAL LOAD SHED ' 4.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0616 FREQUENCY =58.151 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.725 100.00 PERCENT OF”INITIAL LOAD SHED 3.4 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0980 FREQUENCY =58.149 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.767 100.00 PERCENT OF INITIAL LOAD SHED 7.9 MW AND 2.4 MVAR (NOMINAL)SHED.VOLT =1.1215 FREQUENCY =58.176 BERNICE SERNICE SOLDOTNA 0.0 9988 "°°9989 SOLDOTIG 0.0 arteam:loc 2.2 2.3h .¢flo.o <y""0.0 eo,"<5.8 77.3 "<YJo.d 0.0001,™@DAVESCRofS]t 0.994 3yg.0 lo.968 9986 Ths =5.1 5.8 -i3.2 SOLD Svs =CEBo e t =-9$ 112.9 o si7 =eERt-Karda 0.0 ng---f499.21@)2-2 4508 SZ gn 209.00.0 ie---a a ° 25.6 QRTZ CR7.9 -.re]3.2 1.al1a.2°2 5 9907reek 0.977 SKI HILL =33.5 DA3H=320 -i3.4 84 "1.8 1.7.2 9996onseteweoweweoseon WIT)LAWING 6.7 tT nanEsORO.| 65 a SKI HILL 38 * 1 -” - ow "EY 2.023 46.9 SSpmtrey l4 KASILOF 74 17.49-20.9pemmeenewwwweeeeeeeean ANCH PT 3% 78 t 14.)KASILOF BEAVR TP,70 $ iy oral4So1,7)-14.0ww ° Daal t " . o '..BOOSBOBSSDESHRSTETTSSSHASSSSHSTESTSHSOSBHETSBSSBesTeeseeseeneetsceneefHeenanawanaeORTZ CR *e 0.999999 an wn 713.6"FRITZ CR 9997 Leewesewesnn FRIT2CR1.1060ofaly|WINTER 1990.CASE 2.46.4MW ANCH EXPORT,41.3MW KENAI IMPORT BERNICE LAKE 3 AND COOPER 1 &2 ON-LINE. THU.JUN 06 1991 16:53 KV:«69 .€127138 210 -3.293.08BERNICE BERNICE SOLDOTNA HOPE 9.0 9988 °°9989 SOLDOTIG 0.0 de 49 O.0 '-21.2 21.48 o¢ flo.o CT}a 0.0 ed 8.9 @.0 <Yo.d 0.000:DAVEScR |!0.0 0.965 966 t 0.0 28.7 SOLD SVS _ ° :0.0 96 a « be -.Cal6.12 a""3 0.90 ye----_tea 8 0-20.0 seed -Z ee 200.0 o.op 7 -s °o a 12.8 ORTZ CR L7on ene"S a -34,61-32.10.951 SKI HILL 33.8 23.8 a4 0.8 1.if[3.0 o 1.005 SKI HILL©33.4 98 :QRTz cr "ZY =$993 ae ba a ae a7)CO TESORO |S 0.950 ' 69 the 23.7 i 1 ' :o .'COOP LK vy 1 9991 - 4 1.929 '0 "9-9 texastnor GI"0.985 83 , ao a '74 thes 6.7 SOLDOTNA a=|:os '"7-t *eety@:¢ar i oli .t i) t ' t beewm eee wear wen ewonas ' BEAVR TP,0.941 26.4- whew ala 80 BEAVR CR a ANCH PT a/|™ pin a2 C=)Coa]t ANCH PT oDIAMROGo/%0.9979965tin28.7 "ws %absaraerelv|!23 o 3.6 -o a FRITZ CR BRAD LK 9997 500 4.2t_os__llo.e8.0.0 12.3 3.7 aeSo -14,0 Lan ak 12.47)25-35 L.7H-6.2 3.7 3 12.9 1 fot 0.4)a02 1.021=26.1 23.7 BRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE.[WINTER 1990.CASE 2.46.4MW ANCH EXPORT,41.3MW KENAI IMPORT |FRI.JUN 07 1991 14:57 WINTER 1990.CASE 2.46.4900 ANCH EXPORT,41.5004 KEMAI IMPORT WINTER 1990.CASE 27.46.4900 ANCH EXPORT.41.J000 KEMAI IMPORT BRADLEY LAKE 1 AND COOPER 1 6 2 ON-LINE.ea BRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE.z aTRIPOAVESCREEK-ONIVERSITY 1LISKV W/O FAULT.bd w)TRIP GAVES CRELK-UNIVERSITY L1SKV W/O FAULT.+fa) NO UNDERFREQUENCY LOAD SHEDDING EWABLEO.2 =WITH ONDERFREQUENCY LOAD SHEDDING ENABLED.2= FILZE:WInzsi .Can n FILL:WINZB2.CaN "a 22 232323 Zz =zo z= =.FaZzZz JOLDOTMA LLSRY voRtagt spy -_--.3 [i390 =-_---9.0608 |22 #3 L souoctas Lisay recat int)-a a161.000 -s 36.000 <Pao) T TTT T T T T T E & |rs : t "4s . EE .{- L i :i {=: f 23 23 -7 « * J ¥¥ |€©= \:: _\-l:be 'es3 3 =\4?s -os \a _-t {i =}it l i I: WINTER 1990.CASE 2.46.40 ANCH EXPORT.41.308 KEMAI IMPORT WINTER 1990.CASE 2.46.4907 ANCH EXPORT,41.3004 KREMAL IMPORT BERNICE LAKE 3 ANO COOPER 1 &2 ON-LINE.3 a SZRNICE LAKE }AND COOPER 1 6 2 ON-LINE."QOTRIPDAVESCRECK-UNIVERSITY 115KV W/O FAULT.=Cal TAIP DAVES CREEX-ONTVERSITY 115KV W/O reur.2 G) NO UNDERFREQUZNCY LOAD SHEDOING ENABLED.2 =WITH UNDERFREQUENCY LOAD SEEDOING s = FILZ:WINZA1.CHN "a PILE:WIM2A2.CaN a 22 222928 z Oo z > ao a= -=a L Qu oeJOLDOTMALI3KVVOLTAGEipyn.JSLDOTRA290)VOLTAGE pry)[ivie00 a arPST|ba howe i)ae}Le)L JQUDOTHA_LIDEV PREQUENCT ig)boss wei (CV b egret 7 T T TTT T T T T 3 T TT 1 T T T T T T rs a |Be}a | Lo |z \: |TOLL |a 5 iz =|i _|= |23 |38 |*y |*y ;g &|iz Z 3\4:=|4: : \i /ws \=". |:: _o "a 'oe ee 1 L L C KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 2.46.4MW ANCH EXPORT,41.3MW KENAI IMPORT BERNICE LAKE 3 AND COOPER 1 &2 ON LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.317 FREQ 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.317 FREQ = 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.400 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.458 FREQ = 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ = 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ = 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.483 73.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =0.9983 FREQUENCY = LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =0.550 FREQ 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.550 81 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ 84 STAGE 2 PICKUP TIMER STARTED AT TIME =0.558 FREQ = 85 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ 86 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ = 691 STAGE 1 BREAKER TIMER STARTED AT TIME =0.558 87 STAGE 1 BREAKER TIMER STARTED AT TIME =0.592 88 STAGE 1 BREAKER TIMER STARTED AT TIME =0.592 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.633 47.00 PERCENT OF INITIAL LOAD SHED 4.0 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =1.0007 FREQUENCY = LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =0.642 86 STAGE 1 BREAKER TIMER STARTED AT TIME =0.642 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.642 100.00 PERCENT OF INITIAL LOAD SHED 11.7 MW AND 2.7 MVAR (NOMINAL)SHED.VOLT =1.0161 FREQUENCY = LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =0.650 85 STAGE 1 BREAKER TIMER STARTED AT TIME =0.650 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.675 100.00 PERCENT OF INITIAL LOAD SHED 5.3 MW AND 1.2 MVAR (NOMINAL)SHED.VOLT =0.9605 FREQUENCY = LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.675 27.00 PERCENT OF INITIAL LOAD SHED 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =0.9864 FREQUENCY = 58.984 58.984 58.491 58.478 58.478 58.418 58.194 58.186 58.183 58.184 58.184 57.962 57.928 57.908 57.908 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.683 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.725 100.00 PERCENT OF INITIAL LOAD SHED 4.3 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.1261 FREQUENCY =57.837 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.725 100.00 PERCENT OF INITIAL LOAD SHED 2.8 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.1265 FREQUENCY =57.839 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.733 56.00 PERCENT OF INITIAL LOAD SHED4.5 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.1148 FREQUENCY =57,827 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.733 100.00 PERCENT OF"INITIAL LOAD SHED 3.4 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.1636 FREQUENCY =57.824 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.767 100.00 PERCENT OF INITIAL LOAD SHED 7.8 MW AND 2.4 MVAR (NOMINAL)SHED.VOLT =1.1853 FREQUENCY =57.852 KENAI LOAD SHEDDING RELAY RESPONSE. WINTER 1990.CASE 2.46.4MW ANCH EXPORT,41.3MW KENAI IMPORT. BRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE. EXISTING SETTINGS. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. 100.00 PERCENT OF INITIAL LOAD SHED 4.7 MW AND LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.9 MW AND 0.667 LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.308 FREQ = LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.308 FREQ = LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.392 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.458 FREQ = LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.458 FREQ = LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.458 FREQ = LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.475 73.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =0.9323 FREQUENCY _LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.542 LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =0.558 FREQ LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =0.558 FREQ LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =0.558 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =0.583 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =0.583 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.625 47.00 PERCENT OF INITIAL LOAD SHED 4.0 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9286 FREQUENCY = LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =0.642 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =0.642 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.642 100.00 PERCENT OF INITIAL LOAD SHED 11.6 MW AND 2.6 MVAR (NOMINAL)SHED.VOLT =0.9530 FREQUENCY = LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =0.650 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =0.658 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.667 0.9 MVAR (NOMINAL)SHED.VOLT =0.9844 FREQUENCY = 0.4 MVAR (NOMINAL)SHED.VOLT =0.9891 FREQUENCY = 58.986 58.986 58.486 58.486 58.491 58.435 58.191 58.194 58.193 58.193 58.192 58.010 57.969 57.937 57.937 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.683 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.725 100.00 PERCENT OF INITIAL LOAD SHED 4.2 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0321 FREQUENCY =57.879 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.725 100.00 PERCENT OF INITIAL LOAD SHED 2.7 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0288 FREQUENCY =57.874 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.733 100.00 PERCENT OF INITIAL LOAD SHED3.3 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0526 FREQUENCY =57.867 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.742 56.00 PERCENT OF"INITIAL LOAD SHED 4.6 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0273 FREQUENCY =57.883 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.767 100.00 PERCENT OF INITIAL LOAD SHED 7.7 MW AND 2.3 MVAR (NOMINAL)SHED.VOLT =1.0876 FREQUENCY =57.870 DAVE SVS 986BERNICESERNICESOLDOTNA HOPE 22 9988 forse 9989 SoLpotic 0.0 -}e--493.2 s 4.7 -«.7f|_as {s.2 7)0.0 "<"1.3 0.5 "<Jia.3 0.0001 © DAVE 'ae a §.9 1.021 9986 1 The sae. 363 713.3 SOLD Svs a eo (f .-0§={10.0 5 no gle$.15 ae 9.0 yp ----fep 80.2)' 3.4 ed "Zs ee 200.0 1.3 tw <°°.r--)a 30.7 QRTZ CR7.9 a 4.51.7 3.8 ese 9987 2.15""s ia 1,019 SKI HILL =30.3 9A -27.6 12.9 04 3.8 -S.i5.2 .i 1.027 LAMING SKI HILL &1.020 '8, 38 '-13.7 $oRTz cr "SY 1,027 ™(H 9993 -7.8 w a ww aie ale sotpotna SY 0.983 H slo ale TESORO «|:1.018 9992 \' 69 itt -13.0 +] +i] 1 1 'i A 'aw''COOP LK wit 1.029 ww ''9991 =IT =7.14'a1.043 '2 '46.1 "83KASILOF '==1 KA %SOLDOTNA 'Ata als ela 'a ' ”':'aQ'=;aS ats'H ao elo t 4 ' '' 1 ' 1 4 ''bewweenr cmap wom me ans 'BEAVR TP,0.972 ' 70 "14.9 ' ='as '"we a i 6 t ao i BEAVR CR ' ' ' °1ANCHPT&0.959 ' 75 '-18.0 'Dn i]a 'ww i] ”t t 4 i] ' f] i] t tPlaJ DIAM RDG SIS 0.948 '9965 ae -18.8 'oln ' %_sto '=:2514.7 i zs >6 4.8 ' -_Qo ' a ' ' Ll FRITZ CR \BRAD LK 9997 \scO ae |i See AL.0.0 -2.0 0.5 r-4o eee |Crs Sees |L°PE °){)ne aos 2.0 ce 0.0 1 57%0.50.948 10.000=s-18.8 0.0 WINTER 1990.CASE 3.43.5MW ANCH EXPORT,38.6MW KENAI IMPORT BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE. ITHU.,JUN 06 1991 17:05 "Us.eca 21%0 «a07Nn DAVE svs BERNICE BERNICE SOLDOTNA gee HOPE 0.9 9988 f°"9989 SOLDOT1G ool >«49 2.0 | ie -22.8 23.0 o¢foe 5°"0.0 '"<"9.5 8.7 <yo.o 0.000 1lea ri0.0 us heosFieteSOLDSVSi [orl o ft |-of -2.9 °S mo i tal$1555 an 0.6 29 SOg.0}3,*-55 Zz se go0.00.0 -a a =ORTZ CR7wa-4.9 99871-8ll9.ace :zee -30.sH-27.50.946 SKI HILL 29.822.0 a4 0.6 0.52.3 9996 1,002 LAWING 31.2 QRTZ cr "SY 1.009999331.7 anim ainalowileaie7'TESORO LS 69 at ins i t t 'a Coop LK yl 1.013.9991 mln 32.4"xv 'Soe1.047 ' "11.7 ' aig mi 'ye oN+a os ' -_t eeeqd)'sa ed barL)ol iv .1 a i] I 4 Leweeeeeeenafmceeeena 4 SEAVR TP 0.935 70 24.5---Ce Dedale 80BEAVR CR ANCH PT ©O]%0.996 75 ole 24.9eeend37S me Lali) ane 1.0618 =3p.0 86 ANCH PT DIAM RDG "]™1.000 9965 ale 25.0 fed Le) %|seae26p14.7)TI]!a >o 4.635g a FRITZ CR BRAD LK 9997 500 12.7 ak 16.0 59.9 n<8.3 18.1 6.7 «20.2 20,4 ot 227)w Nnwas 2.0][-7.2 5.2 med a.3 leoS$0.5)007 1.031 "a -25.6 27.9 WINTER 1990.CASE 3.43.5MW ANCH EXPORT, BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE FRI,JUN 07 1991 14:52 38.SMW KENAI IMPORT wu.wea write anan WINTER 1990.CASE 3.43.Sef ANCH EXPORT,36.5 KENAI IMPORT WINTER 1990.CASE 3.43.5M!ANCH EXPORT,30.S90 KENAI IMPORT BRADLEY LAKE 1 4 2 AND COOPER 1 &2 ON-LINE sa BRADLEY LAKE 1 &2 AND COOPER 1 6 2 ONLINE 25TRIPDAVESCREZK-UNIVERSITY 115KV W/O FAULT.3a TRIP DAVES CREEK-CNIVERSITY ine .ca NO UNDERFREGUENCY LOAD SKEDDING ENABLED.2=WITH UNOZRFREQUENCY LOAD SKEDO ENABLED."= FILE:WIN3B1.CAN "”TILE:WIW3IB2 .CHN sa2623 Sm z=xz2$2= >a eSOLBOTMA_LLSEY VOLTAGE {Pal[1.3000 -<<so,50008 te -_--=0.eee <SOLROTMA LISkY rarourecs cer).{peSOLALEYEBECY RL)-_-J (62.000 --<_6.008 3 -_-_+.000|a i 1 im ||if J 1 |og t(j ot i}}i t |E{3 |z \| . 7 |l £ |z \: |-={= is + |28 \23smta="37 \73\g :e «}ig -.s -\-.- ". .|2 :3 F 2 =Lo {="<-"© &_"I. 2 :i=« "« !!j L Lh WINTER 1990.CASE 3.43.56 ANCH EXPORT,38.6M0 KENAI IMPORT WINTER 1990.CASE 3.43.So ANCH EXPORT.38.6p KENAI ID@ORT BERNICE LAKE 2.3 &4,COOPER 1 &2 AND SOLOOTNA ON-LINE.za BERNICE LAKE 2.3 6 4.COOPER 1 &2 AND SOLDOTNA ON-LINE.2aTRIPOAVESCREEX-ONIVERSITY 115KV W/O FAULT.ta)TRIP OAVES CREEK-UNIVERSITY 11SKV W/O FAULT.2 NO UNDERFREQUENCY LOAD SHZODING ENABLED."=WITH UNDERFREQUENCY LOAD SMEDDING ENABLED.= PILZ:WINJAL.CAN a FILE:WIN3A2 .CAN a Sa =a24=¢.2A 2n =x fo)z =a B =2)z Rea 2 20]|AOLDOIMA LL9FY VOLT Na try)ge1k.3000 _-_-__--9.0000 ft |i.se0ee _---_6.2000 |oO |SOLDOTHALIIEYPREQUERCT(25)bemsee ADMRETRA LG PRROUEASE BE)Ol baw Tar I i i!J q |i 1 i iz }i]am)|]j qT i fi|2 |z=a ie *"1s. -|--|+ |Fy : - i3 is L |ai =|i |-3 |23sata 3 ¥| F |2 _=-=z |.| za|43 ws | L i LE \ ] :|:3 5L4:5 \: ) . ) !!it l t i 1 JL a 1 l !i i }1 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 3.43.5MW ANCH EXPORT,38.6MW KENAI IMPORT BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. -LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =1.200 FREQ =58.999 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =1.200 FREQ =58.998 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =1.283 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.367 73.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0185 FREQUENCY =58.958 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =1.433 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =.1.517 47.00 PERCENT OF INITIAL LOAD SHED 4.8 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =1.0258 FREQUENCY =58.953 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 3.43.5MW ANCH EXPORT,38.5MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.567 FREQ =58.996 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.567 FREQ =58.995 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.650 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.733 73.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9117 FREQUENCY =58.747 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.800 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.883 47.00 PERCENT OF INITIAL LOAD SHED 4.7 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =0.9249 FREQUENCY =58.551 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.933 FREQ =58.499 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.933 FREQ =58.499 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.942 FREQ =58.493 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.042 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.058 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.058 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.125 100.00 PERCENT OF INITIAL LOAD SHED 11.4 MW AND 2.5 MVAR (NOMINAL)SHED.VOLT =0.9701 FREQUENCY =58.290 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.142 100.00 PERCENT OF INITIAL LOAD SHED 5.7 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =0.9526 FREQUENCY =58.282 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.142 27.00 PERCENT OF INITIAL LOAD SHED 2.3 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =0.9674 FREQUENCY =58.282 LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =1.500 FREQ =58.199 LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =1.500 FREQ =58.200 LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =1.508 FREQ =58.199 LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =1.508 FREQ =58.199 LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =1.517 FREQ =58.199 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =1.583 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =1.592 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =1.600 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =1.600 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =1.642 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =1.667 100.00 PERCENT OF INITIAL LOAD SHED 5.0 MW AND 1.0 MVAR (NOMINAL)SHED.VOLT =1.0876 FREQUENCY =58.151 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.675 100.00 PERCENT OF INITIAL LOAD SHED 3.2 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0899 FREQUENCY =58.147 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.683 56.00 PERCENT OF INITIAL LOAD SHED ' 5.6 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =1.0495 FREQUENCY =58.150 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.683 100.00 PERCENT OfINITIAL LOAD SHED 4.0 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.1022 FREQUENCY =58.147 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.725 100.00 PERCENT OF INITIAL LOAD SHED S.1 MW AND 2.7 MVAR (NOMINAL)SHED.VOLT =1.1308 FREQUENCY =58.180 BERNICE BERNICE SOLDOTNA 99900.1 99a8 f 9969 SOLDOTIG 0.0 -}+--a8.8.7 $4.9 =4.off__¢_flo.o o 0.0 '"e 2.0 =3.7 "Ss YO.0 0.0001 |, DAVE 'PS 9.0 0.998 9986 eer be 0.0 710.8 SOLD Svs 7 p= e _-=-0§-0.0 ==.z=sc3.72 a"0.0 4e-_--$end0.2)o.ol] >Peck:"2 gn 900.0 0.0 -a FS ° zi.3 QRTZ CRot7.009,508 *-8 9987 T6S0 re B>8 1.001 SKI HILL -27.0 27.S87-24.5 10.5 64 -3.5 Le7H-1.8 7 1.019 LAWING o q =6SKIHILL&'° w''RTZ cr VEY 1.019cyH9993-5. o ry re aes"|'alo slo Tesoro '=7"lo 1.00269TI?=10.5 ' =t t ' 1 i 1 ' ''bad ;''COOP LK wi™1,022 uy 1 '9991 alo S.3 : <KASILOF &'slo =p \74 1 i]akraneloHrayH(1 )1 boat ] po no 'H -jo elo 't 8s a 'KASILOF \' LS § ''BEAVR TP!0.953 ' 70 Li wl2.1 ' oy"'ain t ' ' 4 eo ' BEAVR CR ' ' - ' .tANCHPT30.949 ' 75 '-14.8 ' =mn '- a ' t t ' ' a t t"le.1 DIAM RDG TIA 0.940 :9965 tht -15.4 'wolw i] oO -_Ho \ary elic?' 'zs 6 3.5 ' _°o '4 a t e t FRITZ CR \BRAD LK 9997 '500 nn |Ser See |(-F)0.0 -1.6 "0.4 azrea)Ee |Coney Sn |A°PE")og Bef -is 0.0 5°.9.4Yo.940 0.000"7 -15.5 0. SPRING 1991.CASE 1.36.4MW ANCH EXPORT,32.8MW KENAI IMPORT BERNICE LAKE 4 AND COOPER 1 &2 ON-LINE. FRI,JUN 07 1991 09:03 'KV:h9 «19K @710 -DAVE svs 906BERNICEBERNICESOLDOTNA HOPE0.0 9980 an 9989 SOLDOT1G gc 0.0 ie 4 0.0 |g -16.0 16.1f _o¢fle pj***0.0 'v<-5.7 4.3 "S $O.0 o.c0c0 s @DaveSocR|aye 1.03532-2 0.998 9986 4S 32.3 0.0 25.4 SOLD SVS min o[m°s »§-0.0 98 &w=zie =I3,72 a"r 0.0 nw '9.2Qsof-}e--5a "Zz oe god.00.0 "a a 2.2 QORTZ CR4.5 ao oo 3.5 9987 1.650 g -27.7-24.60.989 SKI HILL 27.2 24.2 a4 1.6 -0.31/-0.5 9996 1.030 LAWING 31.2 ortz cr "XY 1.02 9993 31.7 Nuns minalofnTESOROisa'FT 69 TIP ' Lt A 'ae COOP LK }.5 1.02 991 =IT 32.3 i aSSSS_-_-_-= t 'yw oNt '> 'Hlo elo t a A 1 t 'KASILOF t bem mm wm www olin we wens 1 BEAVR TP)0.969 70 L_25.6 oynm ale ao BEAVR CR aa] ANCH PT 1.013758D$.5 = o 1 DIAM RDG TIS 1.0149965slo25.5onlLind &-Weay11,7}7TI' s 38 3.3ze| a FRITZ CR BRAD LK 9997 500 $.?0.0 2.9 0.0 2)12.1 2.9 zy "13,7 13.8 os 19.5 I)2g-ee3--s]>->0.8 fs 4.5 sos 0.4;017 1.029 "-25.9 27.5 SPRING 1991.CASE 1.36.5MW ANCH EXPORT,32.8MW KENAI IMPORT BRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE. FRI,JUN 07 1991 15:10 KV:69 .€138 .@230 SPRING 1991.CASZ 1.36.59 ANCH EXPORT,32.810 KENAI IMPORT SPRIWG 1991.CASE 1.36.S6@¢ANCR EXPORT,32.6904 KEMAI IMPORT SRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE.za BRADLEY LAKE 1 AND COOPER 1 6 2 ON-LINE.22TRIPDAVESCREEK-UNIVERSITY 115KV W/O FAULT.2 TRIP OAVES CREEK-UNIVERSITY 11SKV W/O FAULT.2NOUNDERFREQUENCYLOADSHEDDINGENABLED.4£=WITH UNDERFREQUENCY LOAD SREODING ENABLED.25 FILE:SPRIB1.CAN Cz)FILE:SPRIB2.CHN 2223 =a 20 23ax5>.poseuaevasa ie meJi.3000 -_--- 0.20008 bc 3.2000 -_---6.20000 a =J0LDOTEA LSKy raQumECe tat)___-_-1 6 ke ACLRSOMA L3SEY FREOTENCT 185 -_-_-1}3(61.000 -_-_-_-_-se se.a0e |Ss 61.060 -_-_-_-e 346.000 |a if i uf i ||I :P=)q a |I 1 i t 1 iE |a =|-# |:aE: |- .|: |78 \das|*s i \€«E = =\a4:4: (E E '.: \=3oy!l i !cc !l i SPRING 1991.CASE 1.36.404 ANCH EXPORT,32.8M@ KENAI IMPORT SPRING 1991.CASE 1.36.4MM ANCH EXPORT,32.602 KENAI IMPORTBERNICELAKE4ANDCOOPER1&2 ON-LINE.'20 BERNICE LAKE 4 AND COOPER 1 &2 ON-LINE.2aTRIPOAVESCREEK-UNIVERSITY LISKV W/O FAULT.203 TRIP OAVES CREEK-ONIVERSITY 11SKV W/O FAULT.eax)NO UNDERFREQUENCY LOAD SHEDDING ENABLED.£<=x WITB UNDERFREQUENCY LOAD SHEDDING ENABLED.2=FILE:SPRIA).CaN 7)FILE:SPR1A2.CAN ” 2a ze2323 23 aSBSz =oOgumiJOLPCTBA_JIZEV VOLTAGE (95)J AQUROTRAUIEVOTAR[Py]Fivises -=0.30000 |be bese -_--o.s0e8|13) IORPOTRA LLGEY PReOCy 8S)Loss caer]ra)baer aIIaea]J q E J ty !I J 1 |i i Ere .LL |4:|4: .|3 |-« L ||-L | Lo 23 28|-g |s g |f”l - =+=La =|$=|- a i 4 .'i a i < KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SPRING 1991.CASE 1.36.4MW ANCH EXPORT,32.8MW KENAI IMPORT BERNICE LAKE 4 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.400 FREQ = LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.400 FREQ = LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.483 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.567 73.00 PERCENT OF INITIAL LOAD SHED 3.0 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =0.9532 FREQUENCY - LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.592 FREQ LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.608 FREQ LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.608 FREQ _LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.633 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =0.692 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.717 47.00 PERCENT OF INITIAL LOAD SHED 3.8 MW AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9671 FREQUENCY = LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =0.733 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =0.733 LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =0.742 FREQ = LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =0.750 FREQ = LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME 0.750 FREQ = LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME 0.750 FREQ = LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =0.750 FREQ = LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.775 100.00 PERCENT OF INITIAL LOAD SHED 8.3 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =1.0049 FREQUENCY = LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.817 100.00 PERCENT OF INITIAL LOAD SHED 4.8 MW AND 1.0 MVAR (NOMINAL)SHED.VOLT =0.9667 FREQUENCY = LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.817 27.00 PERCENT OF INITIAL LOAD SHED1.9 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =0.9930 FREQUENCY = LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =0.833 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =0.833 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =0.842 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =0.842 58.994 58.993 58.566 58.500 58.482 58.482 58.240 58.199 58.185 58.183 58.184 58.186 58.140 58.107 58.107 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.875 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.917 100.00 PERCENT OF INITIAL LOAD SHED 4.1 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0834 FREQUENCY =58.004 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.917 100.00 PERCENT OF INITIAL LOAD SHED 2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.1092 FREQUENCY =58.006 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.925 56.00 PERCENT OF INITIAL LOAD SHED 4 4.3 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0902 FREQUENCY =58.002 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.925 100.00 PERCENT GPINITIAL LOAD SHED 3.2 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.1142 FREQUENCY =57.997 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.958 100.00 PERCENT OF INITIAL LOAD SHED 7.4 MW AND 2.2 MVAR (NOMINAL)SHED.VOLT =1.1378 FREQUENCY =58.066 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SPRING 1991.CASE 1.36.5MW ANCH EXPORT, LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS BRADLEY LAKE 1 AND COOPER 1 &2 ON-LINE. 32.8MW KENAI IMPORT. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. 83 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER STARTED AT TIME 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 73.00 PERCENT OF INITIAL LOAD SHED 3.0 MW LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS -LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS AND 0.6 MVAR (NOMINAL)SHED.VOLT =0.9140 87 STAGE il PICKUP TIMER STARTED AT TIME = 88 STAGE 1 PICKUP TIMER STARTED AT TIME = 691 STAGE 1 PICKUP TIMER STARTED AT TIME = 83 STAGE 1 BREAKER TIMER STARTED AT TIME 691 STAGE 1 BREAKER TIMER STARTED AT TIME 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 47.00 PERCENT OF INITIAL LOAD SHED 3.8 MW LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT 100.00 8.4 MW BUS LODSHD AT BUS AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9155 87 STAGE 1 BREAKER TIMER STARTED AT TIME 88 STAGE 1 BREAKER TIMER STARTED AT TIME 76 STAGE 1 PICKUP TIMER STARTED AT TIME = 81 STAGE 1 PICKUP TIMER STARTED AT TIME 84 STAGE 2 PICKUP TIMER STARTED AT TIME 85 STAGE 1 PICKUP TIMER STARTED AT TIME 86 STAGE 1 PICKUP TIMER STARTED AT TIME 691 STAGE 1 BREAKER TIMER TIMED OUT AT PERCENT OF INITIAL LOAD SHED AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9452 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 4.5 MW LODSHD AT BUS AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9645 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.8 MW LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS AND 0.4 MVAR (NOMINAL)SHED.VOLT =0.9694 84 STAGE 2 BREAKER TIMER STARTED AT TIME 86 STAGE 1 BREAKER TIMER STARTED AT TIME 85 STAGE 1 BREAKER TIMER STARTED AT TIME 76 STAGE 1 BREAKER TIMER STARTED AT TIME TIME = 0.392 FREQ = 0.392 FREQ = =0.475 0.558 FREQUENCY 0.600 FREQ 0.600 FREQ 0.600 FREQ 0.625 =0.700 0.708 FREQUENCY 0.725 0.725 0.758 FREQ 0.758 FREQ 0.758 FREQ 0.758 FREQ 0.758 FREQ 0.783 FREQUENCY = 0.808 FREQUENCY = 0.808 FREQUENCY = 0.842 0.842 0.850 0.858 58.988 58.988 58.576 58.490 58.490 58.486 58.274 58.194 58.190 58.189 58.190 58.189 58.158 58.122 58.123 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.883 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.925 100.00 PERCENT OF INITIAL LOAD SHED 4.1 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0056 FRIQUENCY =58.046 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.925 100.00 PERCENT OF INITIAL LOAD SHED 2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0047 FREQUENCY =58.044 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.933 100.00 PERCENT OF INITIAL LOAD SHED ; 3.2 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0265 FREQUENCY =58.03 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.942 3536.00 PERCENT OFINITIAL LOAD SHED 4.3 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0340 FREQUENCY =58.046 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.967 100.00 PERCENT OF INITIAL LOAD SHED 7.4 MW AND 2.2 MVAR (NOMINAL)SHED.VOLT =1.0551 FREQUENCY =58.061 BERNICE BERNICE SOLDOTNA HOPE 8.6 9988 f°9989 SOLDOT1G 0.0 de a9 9.6 es 3.2 -3.1 ¢_flo.o ep)994 ®0.0 <3.2 74.8 "S Yo.d0 0.0001 &DAVES CR |Sin 1.010.9 0.993 9986 ed ox2 0.0 10.5 SOLD svs ee bd 0.0 =wlo eloi=]be san -vu :3.72 a"3 0.0 nwo 20.2]a 'o.of _Soe "Zz ge see8t-0.60 "-"a s © 22.3 ORTZ CR4.5 1.00.647.209 o 998SHESmsai 0.998 SKI HILL -27.5 28.31-36.2 "10.2 84 0.4 i.lfo.e =2p;9 "Nie '1.005 LAWING SKI HILL AIS Oo 3983 0,907 'eytr°10.§QRTZ CR 1.004-q '9993 -7.3 2°'hoy bey betoleSOLDOTNA'SY 0.957 '229 9/9TESOROSig0.998 9992 "11.3 '169lt"10.2 ett)' t alen ] 1 a 1 I '4 t '° .i 'coop LK Sig 1,004"wy i '9992 olr =-7,3 031 4 '' 2.1 '83 Hwocoa'SOLDOTNA t ma BIN wlan 'e q 'tin aedOQ:see .'H olo-llolo ': '5 a 'KASILOF 'ae Ae ' ':BEAVR TP}0.949 4 70 "11.7 ' -8ahed'aim ¢ ' 4 '80 'BEAVR CR ' a @ t wa t ANCH PT XI.S 0.948 ' 7 rt -i4.2 'ee 1badbard' NO t -”' ' 1' ' 86 }ANCH PT ' s taedOlrf .'DIAM ROG SIN 0.940 '9965 te 14.7 H ole ' }-1s '=s 24510.8 ' zo oS 3.1 ' -_°o ' 2 t § t FRITZ CR 'BRAD LK9997'500 t Leaewewwonn oop4 0.00.0 1.5 -0.3 [4oe as |omer Meee LE)we aes 1.5 8 0.90 ®Doo:0.349.940 0.000..z-14.8 QO. |SPRING 1991.CASE 2.48MW ANCH EXPORT,43.9MW KENAI IMPORT BERNICE LAKE 4 ON-LINE..- FRI,JUN 07 1991 09:11 KV:$69 .£138 .#230 BRADLEY LAKE 1 ON-LINE. JUN 07 1991FRI, DAVE svs BERNICE BERNICE 996 HOPE 0.0 9988 "°°oo 2 49 0.0 4 -15.4 1$.5 0.0 '<5.5 4.1 0.0001 DAVEScR |SIN d 9.0 0.998 9986 Th 35.- 0.0 25.8 «a)Coa bo:0.0 win eloo--be .ES Se *§-4]508 ae--_-30980.2)"\'' 9.0 -%-4 TON Hz s°Qod.00.90 -a s 2.8 QRTZ CR4.07.208 c 9967 sees"Ss Ps 28.11-36.20.969 SKI HILL : 24.4 a4 2.82.6 , 99963.032 LAWING "009 . 7?artz cr "ZY 1.022 $993 30.2 boydbi d bdalesovpoTNa"J od tTEsoRO Sic 0.989 9992 69 tli 24.4 mo 7 ales 1 t $°'coop LK Sls 1.022 wy i 1.9991 olf 30.2 1.027 ' Sl 2C|2|CKASILOF Ct 2.010 8 wie =]'4 by 6.4 SOLDOTNA wa"Ss wiles '- t «eae aeeeeel1'ae ais'oo olo '38' t 'KASILOF ' eees i] BEAVR TP,70 - ro ale ao BEAVR CR So ANCH PT .|1.014 75 '5.9Da .. oS ' 78 a) 86 ANCH PT AM ROG "IS 01s 9965 solo +9 No °bas)baanes2510.8)7TI' se 3S 209-_o a FRITZ CR BRAD LK 9997 500 2 0.0230.0 @) 11.2 2.8 =-12,7 12,8 $18.0 @)ow he >an rs $1.5{/-3.2 6 <4.5 L &°0.3Y1 019 1.029 =26.2 27.7 SPRING 1991.CASE 2.48MW ANCH EXPORT,43.9MW KENAI IMPORT KV:£69 .€138 .8230 SPRING 1991.CASE 2.48 ANCE EXPORT,43.»..0 RENAI IMPORTBRADLEYLAXE1ON-LINE.bi SPRING 1991.CASE o.40:07 ANCH EXPORT.43.9000 KENAI LCPORT BRADLEY LAKE |ON-LINZ. - TRIP DAVES CREEX-UNIVERSITY 11SKV W/O FAULT.29 Hi TRIP DAVES CAZEK-OWIVERSITY L1SKV #/O FAULT.23 NO UNDERFREQUENCY LOAD SHEDDING ENABLED.4£=WITH UNDERFREQUENCY LOAD SHEDOING 2NABLED."= PILe:SPR2B1.CcuN "”PILE:SPA2B2.CEN wo 22 22228 =z 28$2 ==aWJOLDTA1L3RYvoursamire)-----3+.2000 -_--ar z ta -_--_-6.28000 2 <L JQUROTRA LLSKY FREUD az }himser ere 2 Sse CS a :&TTT T T T rT TE L \3 I 3 /| \z !z. ":"1: f g 5 i "a "7 z°7 is¥@ €=s = |:: y,+:4: Lo iE_" "=e ;: =\ "os "| P)!5 a oe f i l ]!C i !I 1 SPRING 1991.CASE 2.a00W ANCH EXPORT,43.9HW KENAI IMPORT SPRING 1991.CASE 2.404W ANCA EXPORT.43.90W KENAI IMPORT LAKE -BERNICE LAKE 4 ON-LINE.bond TRIP DAVES CREEK- UNIVERSITY 11SKV &/O FAOLT.2 8 TRIP DAVES CALEK-ONIVERSITY L1SKV W/O FAULT.bd 8NOUNDERFREQUENCYLOADSHEDDINGENABLED.ax WITM OWDERFRIOCENCY LOAD SALODIWG ENABLED.s= FILE:SPR2A1.CHN 7)FILE:SPR2A2.CuN 7.) 23 23|sa >z5a8 =uwZzxeboguJOLDOTAAJSRVOLTAGEcpu)}#&oe -_--_0.20000 he [iv oe0e -_--=7.eeee |Oo bomsss JODOTMA LAY PeNpoRAST Aa)Oo I |]q 'a or q J t q I if / r / a /28 3 f "8 2 -- -/ /: fg =+ a 4?qb\/ ¢------_.i i i <r I :{!ba !t Le ;Y SPRING 1991.CASE 2. LODSHD AT LODSHD AT KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. BUS BUS LODSHD AT BUS LODSHD AT LODSHD AT LODSHD AT BUS BUS BUS LODSHD AT BUS 73.00 PERCENT OF INITIAL LOAD SHED 2.7 MW AND LODSHD AT 'LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT LODSHD AT 47.00 LODSHD AT BUS BUS BUS BUS BUS BUS BUS BUS BUS BUS BUS BUS BUS BUS 48MW ANCH EXPORT, BERNICE LAKE 4 ON=<LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. 83 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER STARTED AT TIME = 87 STAGE 1 PICKUP TIMER STARTED AT TIME = 88 STAGE 1 PICKUP TIMER STARTED AT TIME = 691 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 76 STAGE 1 PICKUP TIMER STARTED AT TIME = 81 STAGE 1 PICKUP TIMER STARTED AT TIME 84 STAGE 2 PICKUP TIMER STARTED AT TIME 85 STAGE 1 PICKUP TIMER STARTED AT TIME = 86 STAGE 1 PICKUP TIMER STARTED AT TIME = 83 691 87 88 84 86 85 76 83 STAGE STAGE STAGE STAGE STAGE STAGE STAGE STAGE STAGE 1 i 1 1 2 1 1 1 1 BREAKER BREAKER BREAKER BREAKER BREAKER BREAKER BREAKER BREAKER BREAKER TIMER TIMER TIMER TIMER TIMER TIMER TIMER TIMER TIMER PERCENT OF INITIAL LOAD SHED 3.5 MW AND BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 8.3 MW AND LODSHD AT LODSHD AT BUS BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME = 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 4.4 MW AND LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.7 MW AND STARTED AT STARTED AT STARTED AT STARTED AT STARTED STARTED STARTED STARTED AT TIMED OUT AT TIME = TIME TIME TIME TIME TIME TIME TIME TIME 43.9MW KENAI IMPORT 0.283 FREQ 0.283 FREQ 0.367 0.417 FREQ 0.417 FREQ 0.417 FREQ 0.5 MVAR (NOMINAL)SHED.VOLT =0.9487 FREQUENCY 0.492 FREQ 0.492 FREQ 0.492 FREQ 0.492 FREQ 0.492 FREQ =0.517 =0.517 =0.542 =0.542 =0.575 =Q.575 =0.583 =0.592 0.617 0.450 0.600 0.600 0.625 0.625 0.3 MVAR (NOMINAL)SHED.VOLT =1.0247 FREQUENCY = 0.8 MVAR (NOMINAL)SHED.VOLT =0.9827 FREQUENCY = 1.9 MVAR (NOMINAL)SHED.VOLT =0.9797 FREQUENCY = 0.9 MVAR (NOMINAL)SHED.VOLT =0.9972 FREQUENCY = 58.997 58.996 58.483 58.483 58.489 58.341 58.178 58.187 58.182 58.184 58.187 57.787 57.772 57.781 57.782 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.658 100.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.1405 FREQUENCY =57.713 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.658 100.00 PERCENT OF INITIAL LOAD SHED 2.3 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.1717 FREQUENCY =57.719 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.667 100.00 PERCENT OF INITIAL LOAD SHED 2.9 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.1881 FREQUENCY =57.696 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.675 56.00 PERCENT OF INITIAL LOAD SHED 3.9 MW AND -@.6 MVAR (NOMINAL)SHED.VOLT =1.1556 FREQUENCY =57.689 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.700 100.00 PERCENT OF INITIAL LOAD SHED 6.7 MW AND 2.0 MVAR (NOMINAL)SHED.VOLT =1.2339 FREQUENCY =57.731 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SPRING 1991.CASE 2.48MW ANCH EXPORT,43.9MW KENAI IMPORT. ;BRADLEY LAKE 1 ON-LINE.: TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.267 FREQ 58.978 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME ©0.267 FREQ =58.977 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.350 58.486 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =0.392 FREO =58.486 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.392 FREQ LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.400 FREQ =58.479 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.433 73.00 PERCENT OF INITIAL LOAD SHED 2.7 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9346 FREQUENCY =58.321 LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ =58.195 LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ =58.195 LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =0.467 FREQ =58.194 LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ =58.194 LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =0.467 FREQ =58.193 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.500 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =0.500 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =0.517 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =0.517 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =0.550 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =0.550 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =0.558 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =0.567 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.583 47.00 PERCENT OF INITIAL LOAD SHED 3.5 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =0.9332 FREQUENCY =57.773 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.583 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9283 FREQUENCY =57.761 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.592 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.600 100.00 PERCENT OF INITIAL LOAD SHED 4.1 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =0.9933 FREQUENCY =57.729 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.600 27.00 PERCENT OF INITIAL LOAD SHED 1.7 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9929 FREQUENCY =57. LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.633 100.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0299 FREQUENCY =57, LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.633 100.00 PERCENT OF INITIAL LOAD SHED 2.3 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0258 FREQUENCY =57. LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.642 100.00 PERCENT OF INITIAL LOAD SHED 2.9 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0517 FREQUENCY =57. LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.650 56.00 PERCENT GEINITIAL LOAD SHED 3.9 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0514 FREQUENCY =57. LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.675 100.00 PERCENT OF INITIAL LOAD SHED 6.7 MW AND 2.0 MVAR (NOMINAL)SHED.VOLT =1.0898 FREQUENCY =57. 729 690 686 676 683 673 BERNICE BERNICE99909906 9989 SOLDOTIG HOPE 0.0 {fl 9994 0.0 -t--,490.0 x?10.0 10.0 a$__{|6.0 0.0 'v<-2.8 aek "<Y7.8 0.000;@pavecR|oti 1 4.6 2,026 9986 aed 4 2.3 35.9 sgim svs <r=)er°2 i.-ff0,0 rey -aw wlio 3.78,5 nF §-53 ae :$0.2 "|!' 0.0 3.0%<@Z oof.0.0 ie -2 s r-) 19.6 ssf 2 3 0.9 ganz CR6.6116,.42 =pyseeheo 68 1.022 SKI HILL =29.8 30.4f-38.8 35.1 64 3.4 5.05.2 9996 poco nneeennnr eons Si LAWING 'ai.7 'ORTZ CR YS”2.042H999340.2 e batbie ed bed'alo ojowiea'' TESORO Ne t 69 TI7 $ 7 ' 1 a 1 L 1 ' ''ec ''COOP LK colo 1.041 '9991 th)40.2"xy 't ---1.043 !'3.3 '' wlio poy fr)'i]ataalaele'ee a'$ge 6s''o|o ojo |'8s i 'KASILOF 'en Se ' .a''BEAVR TP,0.995 ' 70 35.8 ' ape ' miw ' t t a a0 i BEAVR CR ' ' t aw ' ANCH PT TI:t 7s the 4 Ly AG ' ol a -”t i t ? t t t ' 4an'OG i=)1DIAMRDG21,0.998 '9965 ft 33.2 'mho t ©"19 '33 eats.'25 37° a t ' ' FRITZ CR 'BRAD LK 9997 \500 Lo.-------tg.-lo-9 0.96 -1.3 =0.3 =0,0ovoeOSHSSPSSSMSNRSSSSSSneeseseseaadhs--P=«=4ana$1.3]]0.0 5°0.3o.998 0.000se)33.2 20 SPRING 1991.CASE 3.49.9MW ANCH EXPORT,45.8MW KENAI IMPORT BERNICE LAKE 3 AND SOLDOTNA ON-LINE. FRI,JUN 07 1991 09:23 KV:£69 ,£138 .6230 OAVE SVS BERNICE BERNICE SOLDOTNA 986 9988 9990 9989 SOLDOTIC0.0 |99940.0 S -14.6 14.7 .¢__flo.0 Tns|3.8 S Yo.d @ 0.0 002 6.0 33°95 SOLD Svs = 2 =0.0 se &' 3,72 &ro a 0.0 nw | a tae)0.0 -}+--cee}-3Z en 0.0 "3 z 9.7 4.5 a 4.5 0.616.407TysHegems a 0.993 SKI HILL =29.8 30.4/-38.7 26.4 a4 2.0 3.43.4 . 9996 -1.025 LAWING SKI HILL oi7@ 33.9 |98 the ORTZ cr "SZ”1.025ro999332.3 <7 =|2 oI'alo ooTesoro|G 0.993 |" 65 TIP 26.4 iy t ' 'o'coop LK Sle 1.025 i 1.9563 i t -. 75 ' SoD a 'SOLDOTNA rr";Je Ot 'ee ae@'ae te 'ojo oo 4 i t ' Lewesaieeewwewa ' BEAVR TP!0.976 70 L 27.9 mw mle 80 BEAVR CR wy ANCH PT x 1.016 7s ' as = * DIAM RDG _/@ 1.016 9965 We 27.3 ne by on =o 259.6}'T Pt S825 -o a FRITZ CR BRAD LK 9997 500 o.s os __ilc.o2.8 vs 0.0 @)8.2 2.5 «-9.5 9.6 $10.4wo"rn a 2aanBe1.3][-2.8 Onl <3 1) eo 0.3 z jo SPRING 1991.CASE 3.49.9MW ANCH EXPORT,45.8MW KENAI IMPORT BRADLEY LAKE 1 ON-LINE. FRI,JUN 07 1991 15:19 KV:569 ,£138 .@230 SPRING 1991.CASE 3.49.990 ANCE EXPORT.45.0c0f KEMAI IMPORTBRADLEYLAXE1ON-LINE. SPRING 1991.CASE 3.49.9908 ANCA EXPORT.45.0001 KEMAI IDKPORT BRADLEY LAKE 1 ON-LIWE. TRIP CAVES CREEX-ONIVERSITY 115KV 4/0 FAULT.=Fx nie TRIP OAVES CREZEK-ONIVERSITY LISKV W/O FADLT.:8NOUNDERFREQUENCYLOADSHEDDINGEWAALED.2=WITH UNDERFREQUENCT LOAD SAZDOING ENABLIO.=2 PILE:SPRIB1.caN a FILE:SPA3B2.CEN 7 22--- 2 =z822 z=sigm>}ft Zu[tee -_--6.30006 @ [2 2000 -_--+6.2000 arayCEaeehessniannememmeenetnaemermeaty|e hecsse ----a & 1 |rout t q i i i zs a t i]i if 1 i 1 if qT E ;;PP )73 _|5 -\a a \i |mE:+5 --2|-_\A \a \a 5 jis]Lc is)2 \¥ Y .{+4 ==7 -=e /:;oe .a=]"4 -{o "4 « 2 4 }- :<x - + _:{Vv z =|==s\:ee °-_ --ee eeJ1eee}+!T I i ic I !l -t +I if !i m SPRING 1991.CASE 3.49.9rM ANCH EXPORT,45.00 KENAI IMPORT SPRING 1991.CASE 3.49.9901 ANCH EXPORT,45.0001 RENAI UPORTBEANICELAKE3ANDSOLDOTHAON-LINE.Zo SERNICE LAKE 3 AND SOLDOTNA ON-LINE.4OTRIPDAVESCREEX-UNIVERSITY 115KV W/O FAULT.ta TRIP OAVES CREEK-ONIVERSITY 115KV W/O FADLT.ZoNOUNOLAFREQUEMCYLOADSREODINGENABLED.S=WITH UNDERFREQUENCY LOAD SBEDDING ENABLED.2xPILE:S$PR3A1.CaN 7)PILE:SPR3IA2.CEN 7) 2a 222823 =o a=ax 8 ==2) =SOLDOTMA LLSeY voutagE try)J 20 gei3030iReTT|zt {i.3e00 --7.0008 oO boas Joupemma Lamy reaneeT tag)oO en ee |re H T |2 L +:= | E |2 L |UL |1.e g g>an a-|2.on a37 *_ :2 O..”2 4=.hoo :*_nA SD +- y Vl 4,De 3eeQs_|2 a|. oS s |E i}3 -\=".- ” rs it i !0 i KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SPRING 1991.CASE 3. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 49.9MW ANCH EXPORT, BERNICE LAKE 3 AND SOLDOTNA ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE. 83 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER STARTED AT TIME 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 0.5 MVAR (NOMINAL)SHED.VOLT =1.0862 87 STAGE 1 PICKUP TIMER STARTED AT TIME = 88 STAGE 1 PICKUP TIMER STARTED AT TIME = 691 STAGE 1 PICKUP TIMER STARTED AT TIME = 83 STAGE 1 BREAKER TIMER STARTED AT TIME 691 STAGE 1 BREAKER TIMER STARTED AT TIME 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT 100.00 BUS LODSHD AT BUS 0.7 MVAR (NOMINAL)SHED.VOLT =1.0701 87 STAGE 1 BREAKER TIMER STARTED AT TIME 88 STAGE 1 BREAKER TIMER STARTED AT TIME 76 STAGE 1 PICKUP TIMER STARTED AT TIME = 81 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 2 PICKUP TIMER STARTED AT TIME = 8S STAGE 1 PICKUP TIMER STARTED AT TIME = 86 STAGE 1 PICKUP TIMER STARTED AT TIME = 691 STAGE 1 BREAKER TIMER TIMED OUT AT PERCENT OF INITIAL LOAD SHED 8.2 MW AND 1.8 MVAR (NOMINAL)SHED.VOLT =1.0545 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 3.6 MW AND LODSHD AT BUS 0.7 MVAR (NOMINAL)SHED.VOLT =1.0744 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW AND LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS 0.3 MVAR (NOMINAL)SHED.VOLT =1.0802 84 STAGE 2 BREAKER TIMER STARTED AT TIME 86 STAGE 1 BREAKER TIMER STARTED AT TIME 76 STAGE 1 BREAKER TIMER STARTED AT TIME 8S STAGE 1 BREAKER TIMER STARTED AT TIME TIME = 45.8MW KENAI IMPORT 0.358 FREQ = 0.358 FREQ = =0.442 0.525 FREQUENCY 0.558 FREQ 0.558 FREQ 0.558 FREQ =0.592 =0.658 0.675 FREQUENCY =0.683 =0.683 0.733 FREQ 0.742 FREQ = 0.742 FREQ = 0.742 FREQ = 0.742 FREQ = 0.742 FREQUENCY = 0.767 FREQUENCY = 0.767 FREQUENCY = 0.825 0.825 0.833 0.833 58.997 58.997 58.562 58.499 58.499 58.485 58.277 58.196 58.189 58.189 58.189 58.189 58.189 58.186 58.186 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.867 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.908 100.00 PERCENT OF INITIAL LOAD SHED 3.3 MW AND 0.6 MVAR (NOMINAL)SHED.VOLT =1.0539 FREQUENCY =58.131 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.908 100.00 PERCENT OF INITIAL LOAD SHED 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0783 FREQUENCY =58.130 LODSHD AT BUS 7@ STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.917 56.00 PERCENT OF INITIAL LOAD SHED 3.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0497 FREQUENCY =$8.130 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.917 100.00 PERCENT O8-INITIAL LOAD SHED 2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0681 FREQUENCY =58.128 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.950 100.00 PERCENT OF INITIAL LOAD SHED 6.0 MW AND 1.8 MVAR (NOMINAL)SHED.VOLT =1.0620 FREQUENCY =58.202 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SPRING 1991.CASE 3.49.9MW ANCH EXPORT,45.8MW KENAI IMPORT. BRADLEY LAKE 1 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.208 FREQ =58.978 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.208 FREQ =58.979 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =0.292 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =0.317 FREQ =58.464 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME 0.317 FREQ =58.464 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =0.325 FREQ =58.473 LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT TIME =0.375 FREQ =58.188 LODSEHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT TIME =0.375 FREQ =58.178 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.375 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9174 FREQUENCY =58.175 LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT TIME =0.375 FREQ =58.175 LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT TIME =0.375 FREQ =58.174 LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT TIME =0.375 FREQ =58.170 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =0.425 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =0.442 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =0.442 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =0.442 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED AT TIME =0.458 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED AT TIME =0.458 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED AT TIME =0.467 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED AT TIME =0.475 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =0.500 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.508 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT »0.9298 FREQUENCY =57.494 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.525 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9565 FREQUENCY =57.431 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.525 100.00 PERCENT OF INITIAL LOAD SHED 3.6 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9792 FREQUENCY =57.432 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.525 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9790 FREQUENCY =57.433 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =0.542 100.00 PERCENT OF INITIAL LOAD SHED 3.3 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0039 FREQUENCY =57.378 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.542 100.00 PERCENT OF INITIAL LOAD SHED 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0257 FREQUENCY =57.378 LODSHD AT BUS 85 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.550 100.00 PERCENT OF INITIAL LOAD SHED ' 2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0302 FREQUENCY =57.357 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.558 56.00 PERCENT GF INITIAL LOAD SHED3.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0413 FREQUENCY =57.342 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =0.583 100.00 PERCENT OF INITIAL LOAD SHED ; 6.1 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =1.0566 FREQUENCY =57.302 SUPMER 1990.CASE 1.31.5 ANCE EXPORT.28hn KEMAI IMPORT.SUMMER 1990.CASZ 1.31.S°t ANCA EXPORT,260 KEWAI IMPORT. BERNICE LAKE 3 6 4 ON-LINZ.sa BRADLEY LAKE 1}6 2 ON-LINE.aaTRIPDAVESCRELEK-OWIVERSITY 11SKV W/O FAULT.WITE bal TRIP DAVES CREEK-UONIVERSITY L1SKV W/O FAULT.WITH fa} LOAD SHEDDING ENABLEO.SOLDOTWA RELAY MODIFIED.3 =WAD SHEODING ZNABLED.SOLDOTNA RELAY MOOIFIED.s = FILE:SOM1A2%.CmI "”PIL£:SUM1B2X.CHN "a za<2a23 z=5 a= Fy e j :2LkawSULRITEALLIEYVOLTAGE(Po)a [ivi -_---«0.30008 1°)+t.a808 =aoe |(a) |SCLIN LY SERIO {BRL L 2161.000 ----*34.000 Poe] 1 q v I I l J is i |3 3 =s 3 |:: F 3=z : -- =:Py Fy|¥!¥ is */z * a |A TL ,+ .s 3 a 43 43 L --md=* =45 -: =i !l l |!s !i I I Sonniee cane reheat eta ANCHE SXPORT.Z2OMW KZNAI LAMPORT.SUMMER 1990.CASE 1.31.5 ANCH EXPORT,26MW KENAI IMPORT.LAKE =.=a BRADUZY LAKE 1 &2 ON-LINE.bond TRIP OAVES CREEX-ONIVERSITY 115KV W/O PADLT.WITH °&)TRIP OAVES CREEK-ONIVERSITY LISKV W/O FAULT.2 Px]ONDERFREQUENCY LOAD SHEDDING ENABLED.EXISTING SETTINGS.$=WITH UNDERFREQOENCY LOAD SHEDDING ENABLEIO.EXISTING SETTINGS s=FILE:SOMiA2 .CaW ”TILZ:SUM1B2.CHN an 22 22 A 23 za kK J z5z= a > ae ou)bar g5 kex SOUTER LLSEY VOLTA ti -_---1331.3008 0 7.3006 i YET TT Is |*3hmsssbereaeASMOTEAJAQEYRSS2 1 |S Ul a oa q q I i q i E L :|: S 4; ':"3 :H : ==|= z \z L s \+ 23 s 2327=4:2: ¥/*yif&/.=*<be {+= :F -<tT :I*.=I. a 2 z a 4: KENAI LOAD SHEDDING RELAY RESPONSE.MODIFIED SOLDOTNA RELAY SETTING. SUMMER 1990.CASE 1.31.5MW ANCH EXPORT,28MW KENAI IMPORT. LODSHD AT LODSHD AT BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE. BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =10.650 FREQ =58.997 BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =10.650 FREQ =58.997 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =10.733 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =10.733 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.817 47.00 PERCENT OF _INITIAL LOAD SHED3.2 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9720 FREQUENCY =58.782 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =10.817 73.00 PERCENT OF INITIAL LOAD SHED 2.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9690 FREQUENCY =58.782 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =11.183 FREQ =58.498 LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =11.192 FREQ =58.496 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =11.192 FREQ =58.496 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =11.283 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =11.317 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =11.317 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.367 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =1.0128 FREQUENCY =58.417 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.400 100.00 PERCENT OF INITIAL LOAD SHED 3.8 MW AND 0.8 MVAR (NOMINAL)SHED.VOLT =1.0017 FREQUENCY =58.445 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =11.400 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =1.0184 FREQUENCY =58.445 KENAI LOAD SHEDDING RELAY RESPONSE.MODIFIED SOLDOTNA RELAY SETTING. SUMMER 1990.CASE 1.31.5MW ANCH EXPORT, BRADLEY LAKE 1 &2 ON-LINE. LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS TRIP DAVES CREEK-UNIVERSITY 115KV LINE. 28MW KENAI IMPORT. 83 STAGE 1 PICKUP TIMER STARTED AT TIME = 84 STAGE 1 PICKUP TIMER STARTED AT 83 STAGE 1 BREAKER TIMER STARTED AT TIME = 84 STAGE 1 BREAKER TIMER STARTED AT TIME = 83_STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND -LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME = 0.5 MVAR (NOMINAL)SHED.VOLT =0.8919 FREQUENCY TIME = 0.675 FREQ = 0.675 FREQ = 0.758 0.758 0.842 0.7 MVAR (NOMINAL)SHED.VOLT =0.8910 FREQUENCY = 0.842 1.117 FREQ = LODSEHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =1.117 FREQ = LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =1.117 FREQ = LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.217 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.242 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.242 LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.300 100.00 PERCENT OF INITIAL LOAD SHED 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9327 FREQUENCY = LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.5 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9450 FREQUENCY LODSHD AT BUS 76 STAGE 1 PICKUP TIMER STARTED AT LODSHD AT BUS 81 STAGE 1 PICKUP TIMER STARTED AT LODSHD AT BUS 84 STAGE 2 PICKUP TIMER STARTED AT LODSHD AT BUS 85 STAGE 1 PICKUP TIMER STARTED AT LODSHD AT BUS 86 STAGE 1 PICKUP TIMER STARTED AT LODSHD AT BUS 84 STAGE 2 BREAKER TIMER STARTED LODSHD AT BUS 86 STAGE 1 BREAKER TIMER STARTED LODSHD AT BUS 76 STAGE 1 BREAKER TIMER STARTED LODSHD AT BUS 85 STAGE 1 BREAKER TIMER STARTED TIME = TIME = TIME = TIME = TIME = 1.325 0.7 MVAR (NOMINAL)SHED.VOLT =0.9452 FREQUENCY = 1.325 1.683 FREQ = 1.692 FREQ = 1.692 FREQ = 1.692 FREQ = 1.692 FREQ = AT TIME = AT TIME = AT TIME = AT TIME = 1.775 1.775 1.783 1.783 58.993 58.993 58.781 58.781 58.498 58.498 58.494 58.323 58.313 58.313 58.199 58.200 58.198 58.199 58.198 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER STARTED AT TIME =1.817 LODSHD AT BUS 84 STAGE 2 BREAKER TIMER TIMED OUT AT TIME =1.858 100.00 PERCENT OF INITIAL LOAD SHED 3.3 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0384 FREQUENCY =58.139 LODSHD AT BUS 86 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.858 100.00 PERCENT OF INITIAL LOAD SHED 2.1 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0397 FREQUENCY =58.138 LODSHD AT BUS 76 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.867 56.00 PERCENT OF INITIAL LOAD SHED 3.5 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0459 FREQUENCY =58.138 LODSHD AT BUS 85-STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.867 100.00 PERCENT OF INITIAL LOAD SHED 2.6 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =1.0477 FREQUENCY =58.136 LODSHD AT BUS 81 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.900 100.00 PERCENT OF INITIAL LOAD SHED 6.1 MW AND 1.8 MVAR (NOMINAL)SHED.VOLT =1.0692 FREQUENCY =58.150 DAVE SVS SERNICE BERNICE SOLDOTNA 986 ore 3.9 9ea r.9989 SOLDOT1G 0.0 49 0.0 "Ss "14,7 14.7 .s__flo.o G}994 0.0 aaa"<=5.2 3.8 "Ss $0.0 0.000 +FleDAVES®or d0.0 1.008 9986 ye 0.0 69.8 SOLD Svs ain ofa98ateate °ba p=0g -1028 &-= "cI93.72.6 ©0.0 aw 230.2}oof 2,[roert Ps ga}0-30.0 -3 x ° zt QRTZ CR4.5 )-0.7 50.6 6.5 Soho z 998 1.3m 5 1.000 SKI HILL 10.4 10.5/1-14.8 .6 a4 5.5 T.7 3.2 9996 Ww -1.036 LAWING SXI HILL J 72.4 |98 'QRTZ CR x 1,032'2 9993 71.6scmiseainri=-oloMmiw.' Tesoro)jc 0.999 69 T7 68.5 i ' ' ale 1.032coorLKclo1.'999)rd as OF) t SSS t KASILOF @ =rN J n[)*eee, '7 ae «634s'olo olo 'as 'KASILOF ' ee ' BEAVR TP)0.984 70 L,69.7 wTFiw min a0BEAVR CR ANCH PT "©022 75 4Bn _ Pal i [=] OIAM RDG ™I 1.023 9965 walt 71.7 rFiWm 3 =sloans2609.7?1oOzs292.5 a FRITZ CR BRAD LK9997(°°17.4 S 17.0 "2.1 ns -2.0 2 18.5 1.2 =2 =16,8 16.9 $17.3 -i)ne aes 4.3 0.9 3.2 <72.0 =°*0.301.024 1,029z-72.2 74.3 SUMMER 1990. BRADLEY LAKE TUE,JUN 11 1991 CASE 1B.25.4MW ANCH EXPORT, 1 &2 ON-LINE. 13:32 22MW KENAI IMPORT. KV:S69 ,£138 ,€230 SUMMER 1990.CASE 1.31.5MW ANCH EXPORT,28MW KENAI IMPORT. BERNICE LAKE 3 6 4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:SUMIA2.CHN SOLDOTNA 125KV VOLTAGE (PU)[1.3000 ---€0.30000| SOLDOTNA JISKV FREQUENCY (HZ)163.000 ----*56.000 | rf T I T g Ey --_ -73 -_ 78 a _ i} --_- ="le « 8J|!!!!S TIME(SEC)26.00012.00015:28CT'SW/LOADSHEDJUN121991WED,SUMMER 1990.CASE 1B.25.4MW ANCH EXPORT, BRADLEY LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 215kV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:SUM1B2B.CHN SOLDOJNA_JIS5KV VOLTAGE (PU) 22MW KENAI IMPORT. J3.3000 _-_=0.30000| SOLDOTNA LISRV FREQUENCY (HZ)| 161.000 o----__*56.000 | ||{|||{||3 3 \_.a c-J3L-+: =_ 3 a 4s 1 -_ _._: 3_.1. ||||3 15:28BRADLEYW/LOADSHEDJUN121991WED,TIME(SEC) KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTI NGS. SUMMER 1990.CASE 1B.25.4MW ANCH EXPORT,22MW KENAI IMPORT. BRADLEY LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =0.958 FREQ =58.996 LODSED AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =0.958 FREQ =58.996 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME = LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 73.00 PERCENT OF INITIAL LOAD SHED 1.042 1.125 2.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.8975 FREQUENCY =58.848 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME = LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 47.00 PERCENT OF INITIAL LOAD SHED 1.192 1.275 3.1 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9114 FREQUENCY =58.734 -LODSHD AT BUS 87 STAGE 1 PICKUP TIMER STARTED AT TIME =1.633 FREQ 58.499 LODSHD AT BUS 88 STAGE 1 PICKUP TIMER STARTED AT TIME =1.633 FREQ =58.499 LODSHD AT BUS 691 STAGE 1 PICKUP TIMER STARTED AT TIME =1.633 FREQ LODSHD AT BUS 691 STAGE 1 BREAKER TIMER STARTED AT TIME = LODSHD AT BUS 87 STAGE 1 BREAKER TIMER STARTED AT TIME = LODSHD AT BUS 88 STAGE 1 BREAKER TIMER STARTED AT TIME = LODSHD AT BUS 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 58.498 1.733 1.758 1.758 1.817 8.4 MW AND 1.9 MVAR (NOMINAL)SHED.VOLT =0.9612 FREQUENCY =58.380 LODSHD AT BUS 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 100.00 PERCENT OF INITIAL LOAD SHED 1.842 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =0.9688 FREQUENCY =58.379 LODSHD AT BUS 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME = 27.00 PERCENT OF INITIAL LOAD SHED 1.842 1.5 MW AND 0.3 MVAR (NOMINAL)SHED.VOLT =0.9686 FREQUENCY =58.379 DAVE Svs 986BERNICEBERNICESOLDOTNA HOPE 0.0 9988 °°9989 SOLDOTIG 0.0 ie a9 0.0 as -9.6 9.6 <_flo.o 9994 3-0 1"<72.9 1.2 "S YO.9 0.000 1 ' paves?435.0 1.022 9986 2 23.SOLD SVS =DF eo ti |=-p$-12-0 98 S To We *ta.72 a"?0.0 4 e-_--_tegnd-2JQsofleesaeed Z oe goo.0.0 ie 7 hand a =°o 2.3 QRTZ CR4.5 -0.9 z0.6 6.4 Geko ds 998 l.2m oc 63 1.017 SKI HILL =2.8 z.eh7 1 23.1 84 4.1 -0.19-1.9 9996 m 1.035 LAWINGSKIHILL«J 25.0 hw!QORTZ CR "4 2.029--]93 26.8 -Colm atm'wlio wawhes'7TESOROHe1.01 3 Th?23.1 ' 1 i] i] 'ats bed!coop LK slo 1,031asog)y 2s ' >ela 'espeam 'Qq7 9'alo elo'' ' ' 1 KASILOF ' ee ey ' BEAVR TP,0.991 70 23.6- mw mle 80 BEAVR CR ANCH PT @ 1,03278ba)28.2 2 ww ' nan DIAM RDG Sl;1.0339965woh25.5 woe %-palan69.5}1 2a eeB35 a FRITZ CR BRAD LK 9997 500 17.7 xi 20.0 - 2)-1.8 <-1.8 2 15.6 1.2 «*Eo -16,9 27,0 oS 14.8 )2g -gej-i}?-3.3 <"1.8 alfon0.31 .034 1.039="26.0 28.21 SUMMER 1990.CASE 2A.KENAI SYSTEM ISOLATED.BERNICE LAKE 3, BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TUE,JUN 11 1991 13:20 KV:£69 ,€138 ,@230 SUMMER 1990.CASE 2.KENAI SYSTEM ISOLATED. BERNICE LAKE 2,3 &4 AND COOPER LAKE 1 6 2 ON-LINE."aTRIPBERNICELAKEUNIT#4 @ 21.4MW W/O FAULT.=fi]WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.am FILE:SUM2A2.CHN n 4 naa[|QNA 5 = nun ae SOLDOTWA_LISRV VOLTAGE pu)W E4{7.3000 -==+0.30000J 0 {SOLDOTNA _JISKV FREQUENCY (NZ) 161.000 _--*56.000 | es 0 a |3 |*. |45 }|jt ;C4 |3 =8 5iga- |"Te m al Lo |RB * {s _ ,"3 io_B 3 L (+3 iom43 |!!J ||!|3 SUMMER 1990.CASE 2A.KENAL SYSTEM ISOLATED.BERNICE LAKE 3, BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE.re]TRIP BRADLEY LAKE UNIT §2 @ 20MW W/O FAULT.v flWITHUNDERFREQUENCYLOADSHEDDINGENABLED.oes FILE:SUM2B2A.CHN un al aaowtaQaw B = g dSOLDOTNA11SKVVOLTAGE(PU)FyJi.3000 --€9.30000|mSOLDOTNAJ9SKVFREQUENCY[H2}a161.000 {o--_-#56.000 | |1 |i}3 2 gH ,J °%mMa -7 -3 |8 Go3rm2%os 8 st38 4°-e ess"1s =van bid :=la !I -{|{3 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. SUMMER 1990.CASE 2A.KENAI SYSTEM ISOLATED.BERNICE LAKE 3, BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP BRADLEY LAKE UNIT #2 @ 20MW.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =1.175 FREQ =59.000 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =1.175 FREQ =59.000 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =1.258 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.342 73.00 PERCENT OF INITIAL LOAD SHED 2.4 MW AND 0.5 MVAR (NOMINAL)SHED.VOLT =0.9934 FREQUENCY =58.920 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =1.408 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.492 47.00 PERCENT OF INITIAL LOAD SHED 3.1 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0146 FREQUENCY =58.865 DAVE svs 986BERNICEBERNICESOLDOTNA 2.0 f"**9989 SOLDOT1G 9.0 the0.0 +-21.£21.6 ¢flo.o 7"0.0 --, -fT|"7.9 "S YO.o oat °DAVE.bole 1.024(7 0.0 0.983 9986 1 IS 29.4.23.6 SOLD Svs 7 ee °|eos 110-9 =wlse alo$1296 7 ac aaa we gio2}"|! o.ol > Wa.sat ng a 0-00.060 de -Fs 3 se a 6.2 7.9 co ww 3.7 QRTZ CR1.8i9.s°2 ¢2 9987peewee= oc 68 0.969 SKI HILL 22.3 21.6H-15.6 21,7 84 3.0 0.3]]/-0.6-3b.0 = 1.0562 "15.3 9996 "77.5 1.021 LAWING SKI HILL s/™ ="E002 1,002 28.7 98 oe?°°25.1 ertz cr YX”-s_1.020 (9993 29.8 ba ore mie iNaleSOLDOTNA %0.969 sia SloTESORO|;0.968 9992 24.5 , 69 tht 21.6 oir =AIMalaaaciciL ' : OOP LK cle 1.023aCc. '1.1016 9991 IP 3065 1 =3):-- i KASILOF |=83174imSOLDOTNA al 'an,« '7 =n aia'Blo alo ' ' 'KASILOF 4 ee ' BEAVR TP}0.959 70 :24.0 [ot Undale 80 BEAVR CR ANCH PT 1.014 75 4.9 - DIAM RDG ©/@ 1.0179965wlo25.1 a)ha o.a Og=o 12.7{7]! a $8 3.7ze3 a FRITZ CR BRAD LK 9997 °°15.5 as 18.0 D)6.0 "e 4.7 27.6 3.8 Son "19,3 19,5 aS 17.1 @eegeg-2 a <4,7 ed 0.41 .o22 1.039=" 25.7 27.9 ;WINTER 1990.CAS1 1A.29.SMW ANCH EXPORT,2S5MW KENAI IMPORT. :BRADLEY LAKE 1 &2 AND "OPER 1 &2 ON-LINE. |WED,JUN 12 1991 14:2.°KV:<69 ,€138 ,6230 Con)ace ee woot ioe)en)a 2 WINTER 1990.CASE 1.41MW ANCH EXPORT,36.1MW KENAI IMPORT.WINTER 1990.CAS]1A.29.5MW ANCH EXPORT,25MW KENAI IMPORT. BERNICE LAKE 3 &4 AND COOPER |&2 ON-LINE.20 BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK -UNIVERSITY 115KV W/O FAULT.TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.=WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:WINIA2.CHN 2)FILE:WINIB2A.CHN 39baaa " B= on ae SOLDOTRA TESKV VOLTAGE (PU)Be SOLDOTNA LISKY VOLTAGE (PU)[1.3000 "=F 9.30000|O][73000 ==-7 0.30000| I SOLDOTNALISRVFREQUENCY (#2)J |SOLDOTNA 1 5KV FREQUENCY (WE)] [61.000 o=--4 56.000 |[61.000 oo $6.000 | |t {{||1 |3 |J j!||l |||3 é 8 =+s == =--ls -"Ie -7 |3 3 =3 -comeC1|a BS Go|3%"=4a'|g -°e |g &3 =--16 -Te | i a-=f e - PTL a | =-1é -4 -5 .tJI|ra !|it |!S J ||!:$83RADLEYW/LOADSHED141-000WED,JUN121991214,00020.006TIME(SEC)}2.0000 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTE LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS R 1990.CAS1 1A.29.5MW ANCH EXPORT,25MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. 83 STAGE 1 PICKUP TIMER STARTED AT TIME =1.017 FREQ 84 STAGE 1 PICKUP TIMER STARTED AT TIME =1.017 FREQ 84 STAGE 1 BREAKER TIMER STARTED AT TIME =1.100 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.183 73.00 PERCENT OF INITIAL LOAD SHED 3.2 MW LODSHD AT BUS LODSHD AT BUS AND 0.6 MVAR (NOMINAL)SHED.VOLT =0.9253 FREQUENCY 83 STAGE 1 BREAKER TIMER STARTED AT TIME =1.250 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.333 47.00 PERCENT OF INITIAL LOAD SHED 4.1 MW LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS LODSHD AT BUS AND 0.9 MVAR (NOMINAL)SHED.VOLT =0.9383 FREQUENCY 87 STAGE 1 PICKUP TIMER STARTED AT TIME =1.858 FREQ 88 STAGE 1 PICKUP TIMER STARTED AT TIME =1.858 FREQ 691 STAGE 1 PICKUP TIMER STARTED AT TIME =1.858 FREQ 691 STAGE 1 BREAKER TIMER STARTED AT TIME =1.958 87 STAGE 1 BREAKER TIMER STARTED AT TIME =1.983 88 STAGE 1 BREAKER TIMER STARTED AT TIME =1.983 691 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =2.042 100.00 PERCENT OF INITIAL LOAD SHED 11.4 MW AND LODSHD AT BUS 2.5 MVAR (NOMINAL)SHED.VOLT =1.0214 FREQUENCY 87 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =2.067 100.00 PERCENT OF INITIAL LOAD SHED 4.8 MW LODSHD AT BUS AND 0.9 MVAR (NOMINAL)SHED.VOLT =1.0217 FREQUENCY 88 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =2.067 27.00 PERCENT OF INITIAL LOAD SHED 1.9 MW AND 0.4 MVAR (NOMINAL)SHED.VOLT =1.0208 FREQUENCY 58.999 58.999 58.872 58.776 58.497 58.497 58.498 58.404 58.410. 58.410 DAVE svs 9086BERNICEBERNICESOLDOTNA 0.¢9988 r°9989 SOLDOTIG 0.0 Hope O.c +§-22.8 23,0 _.s_flo.o cy"0.0 ,9.4 8.6 <0.0|asa?!oeAVEpaPs 1.91680.0 0.970 6 1 ott 24 0.0 28.8 SOLD svs ar oa S <.=0§-fo.aon FA als ofa $.1 a 0.0 "o.of 2.ase 3%40.9 a 5 1.72,9 ta -1.4 QRTZ CR 1.8|/1\9.8e2 2 9987 Ro 8 Qa. 0.986 SKI HILL -8.7 8.7 H-1 116.7 84 -7.3 3.?-3.9 -3b.0172838 -30.0 9996 75.9 1.023 LAWING SKI WILL J]=I 990 0.990 21.8 8 Se 9.5 ortz cr "S"1.023 q 9993 23.2 a bh rir aim ale soLpoTNA XY 0.958 a"htTESORO)|;0.954 9992 19.4 ' 69 ju 16.6 + '= A 1 'an 'coop LK SI@ 1.017 No 9991 ale 23.9 2,946 '"16.9 et et KASILOF '©[%0.993areaye1mine20.6 ayn als wl '7 fray ajo(1)'na by " =m ain 'ao ej'1.0662 1 85 1 KASILOF t Le wme ewe mewn eh www wens ' BEAVR TP}0.946 18.8-a "ae ale - 80 BEAVR CR ANCH PT @ 1.008 75 1.7 - 7 93 ) 86 ANCH PT _ aleDIAMRDGJc 1.0129965={5 22.2 aia °o -wie ay si4.7|TT! s 4.5zs2 a FRITZ CR BRAD LK 9997 S00 30.8 4 30.0">|Se (ede 26.0 3.4 i -28.0 28.4 as 29.4 @)Soe ::1no-aef-2-2 3.8 2.6 ve 6.7 g°*0.54:018 1.040 =7 23.1 26.4 WINTER 1990.CASE 3A.16.5MW ANCH EXPORT,12MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND "SOOPER 1 &2 ON-LINE WED,JUN 12 1991 15:0 KV:s69 ,$138 ,8230 WINTER 1990.CASE 3.43.5MW ANCH EXPORT,38.6M#KENAI IMPORT BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV 4/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:WIN3A2.CHN SOLDOTWA LISKV VOLTAGE (PU){1.3000 - =T 0.30000|SOLDOTHAJISRYFREQUENCY (HZ)| [61.000 ---1 56.000 | |ae ||I |J | | | { \ { I | |be | - a | | | ---t | g 16.000142.000@.00004.000015:40CT'SW/LOADSHEDJUN1219916.900014.00018.000TIME(SEC)WED,WINTER 1990.CASE 3A.16.5MW ANCH EXPORT,12MW KENAI BRADLEY LAKE 1 6 2 AND COOPER 1 &2 ON-LINE TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:WIN3B2A.CHN IMPORT. SOLDOTRA J2SKV_VOLTAGE (P9) 41.3000 0.30000 | SOLDOTWA JISKV FREQUENCY {H2)| [61.000 oo 36.000 | rT ft TTT TTT 3 Qo ca] =6 -= Qo3 -Ws o3 °o _om Py 98 -'+2 t |l |¢ 3 10.000TIME(SEC)2.000040BRADLEYW/LOADSHED18:JUN121991WED, KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 3A.16.5MW ANCH EXPORT,12MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON=LINE TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =3.217 FREQ =58.999 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =3.217 FREQ =58.999 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =3.300 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =3.383 73.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND (0.7 MVAR (NOMINAL)SHED.VOLT =0.9997 FREQUENCY =58.962 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =3.450 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =3.533 47.00 PERCENT OF INITIAL LOAD SHED =58.9574.7 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =1.0183 FREQUENCY BERNICE SOLDOTNABERNICE HOPE 0.0 9988 f°9989 SOLDOT1G 0.0 a9 0.0 me;-22.8 23.0 $leo Gy"0.0 nes "9.1 8.2 "S Yié.3 0.0001 © pavescR |O19 1.¢ 0.0 |1.007 9986 then 30.u 0.0 23.5 SOLD SVS on CaS To Bo We p--0§-foe}me s\3 leSolaygne0.0 nw 0.2 0.90 -}--4.45 8 OB se”god.0-0 -3 . z 9. 7,9 o om 0.9 QRTZ CR 1.719.899 2.8 9987 2.15%oe a 0.993 SKI HILL 23.5 23,98-19.1 21.6 a4 1.4 =4.093.0 9996 1.034 LAWING 29.2 oRTZ cr VXY 1,032 9993 30.0 mi AinW's ale wilealeolBL7TESORO, 65 mini Ale COOP LK sla 1.032 9992 AIS 30.7---- yr oN nw aw ao elo 'f] we ww ewww ween, 4 BEAVR TP!0.979 70 L 23.8faa)bdale - 80 BEAVR CR t=] ANCH PT oC 75 ? m7 Py i] @ DIAM RDG "I:1.025 9965 alt 24.9 A iePry-_bead BdSey2514.7)TI' za >S 4-5 a FRITZ CR BRAD LK 9997 $00 14.5 S 18.0 @)0.2 os 1.0 2 18.1 2.0 aS 6 720,23 20,3 oS 16.8 G)ne aes 2.0/[-2.5 0.3 <1.0 a ="0.51 029 1.042=”25.5 27.9 WINTER 1990.CASE 3B.34.6MW ANCH EXPORT,30MW KENAI IMPORT. SOLDOTNA,BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. WED,JUN 12 1991 15:44 KV:£69 ,£138 6230 WINTER 1990.CASE 3.43.5MW ANCH EXPORT,38.6MW KENAI IMPORT WINTER 1990.CASE 3B.34.6MW ANCH EXPORT,30MW KENAI IMPORT. BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE.2a SOLDOTNA,BRAOLEY LAKE 1 &2 AND COOPER 1 6 2 ON-LINE.£a TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT.vf]TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT.«(i) WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.eG WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.nae ©} FILE:WIN3A2.CHN n FILE:WIN3B2B.CHN n End w t $9 aa"mm "Oo a4 "2 w B =B = ”ot e Qa ea} SOLDOTRA_1ISKV VOLTAGE (PU)a a SOLDOTNA JIS5KV VOLTAGE (PU)B 4 [1.3000 =F 6.30000 |O] [i-3000 3.30000| SOLDOTRAJISKYFRZQUERCY {HZ)|SOLDOTNA JISKY FREQUENCY {HZ}161.000 -----s 56.000 |161.000 -_----*56.000 |a |j |{|i 3 |}I q |3 3 2 g |g _-_j?_|¢ |a T |s 3 |g |"F a |-e a jee |i |*|z | |2 Lo |_2 3 G a |ge |gu4s=4si )3 6 |§& =_|2 =_|2 e e || a |J2 UL |arwewe|| L -a : ?I "le | a ]JEL 3 ry boon re) * 7!!!I S |l |3 KENAI LOAD SHEDDING RELAY RESPONSE.EXISTING SETTINGS. WINTER 1990.CASE 3B.34.6MW ANCH EXPORT,30MW KENAI IMPORT. SOLDOTNA,BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV LINE.NO FAULT. LODSHD AT BUS 83 STAGE 1 PICKUP TIMER STARTED AT TIME =1.333 FREQ =58.999 LODSHD AT BUS 84 STAGE 1 PICKUP TIMER STARTED AT TIME =1.333 FREQ =58.998 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER STARTED AT TIME =1.417 LODSHD AT BUS 84 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.500 73.00 PERCENT OF INITIAL LOAD SHED 3.7 MW AND 0.7 MVAR (NOMINAL)SHED.VOLT =1.0033 FREQUENCY =58.920 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER STARTED AT TIME =1.567 LODSHD AT BUS 83 STAGE 1 BREAKER TIMER TIMED OUT AT TIME =1.650 47.00 PERCENT OF INITIAL LOAD SHED =58.8694.7 MW AND 1.1 MVAR (NOMINAL)SHED.VOLT =1.0246 FREQUENCY \7POWERTECHNOLOGIES,INC.Xx ONE SIERRAGATE PLAZA SUITE 3408 ROSEVILLE.CA 95678 916 783-3566 TELEFAX 916 783-2086 TELEX 145496 June 21,1991 Mr.Afzal Khan RECEIVED Alaska Energy Authority P.O.Box 190869 JUN 2 rs 1991 Anchorage,AK 99519 DIRECTOR,ENGINEERING DIVISION Dear Afzal: Re:Additional Kenai Import Study At the June 14,1991 TCS Meeting at your offices in Anchorage,we presented the results of the Kenai Import Study previously outlined as part of the load shedding studies.This report compared the load shedding in the Kenai following isolation from the remainder of the system under historical load conditions with CT generation versus the same load conditions with Bradley generation replacing the CT generation. After review and discussion of the study,the Committee requested further analysis.This analysis was to specifically identify,under various generation scenarios,those Kenai import levels (as measured at Daves Creek)at which load shedding transitions (i.e.,no load shed to stage-],stage-1 to stage-2 &stage-2 to stage-3 load shed)would occur in the Kenai following isolation from the remainder of the Railbelt system.This letter report presents the results of this additional analysis. For this study,the following Kenai generation scenarios were selected for evaluation: °A CT-based system with only Bernice Lake 3 &4 on-line. °A hydro-based system with only Bradley Lake and Cooper Lake on-line. °A composite generation system with Bradley Lake and Cooper Lake hydro units on- line along with the Bernice Lake 3 CT. In setting up the cases for this study,we identified two methods for establishing the varying levels of Kenaiimport.The first method was to establish a fixed generation dispatch under each generation scenario and to vary the Kenai import by scaling the Kenai load.The second CORPORATE OFFICES ©1482 ERIE BOULEVARD ©PO BOX 1058 »SCHENECTADY,NY 12301.1058 .$16 374 1220 Page 2 Mr.Afzal Khan June 21,1991 method was to establish a fixed Kenai load level and to vary the Kenai import by scaling the Kenai generation.It was felt both methods had characteristics which could influence the results. Under the first method,the generation under each scenario would have the same dynamic range and offer consistent response to resource deficiencies.For example,a CT with a 25 MW output capability,but with an initial output of 20 MW would always have a 5 MW dynamic range regardless of the Kenai import level.However,under this method the load shedding action would not be consistent due to the variation of system loads for the different Kenai import conditions.For example,a load shedding relay designed to trip 50%of a particular substation's load would trip 2.5 MW when the sub's load is 5 MW,but 5 MW when the sub's load was scaled to 10 MW.Thus more megawatts of load would be shed at each load shedding step as the Kenai load is scaled up to increase the level of the Kenai import. Under the second method,the reverse situation exists.Load shedding would be consistent for all Kenai import levels.That is to say,under a fixed load condition,the same megawatts of load are shed at each step regardless of the Kenai import.However,as generation is scaled under this method to establish different Kenai import levels,the dynamic response capability of the generators is changed.For example,the 25 MW CT could under one case have only a5 MW dynamic response range,but could have a 20 MW dynamic response range under a higher Kenai import condition when the generation is scaled down.This situation could be most influential where only CT generation exists in the Kenai.Since the response rate of CT's is quite fast,a larger dynamic range could potentially be utilized within the time- frame during which load shedding actions might occur. The validity of one study method versus the other is difficult to identify.In actuality,neither method is totally correct.Under actual operating conditions,both Kenai load and generation levels can vary for any given Kenai import condition.However,trying to model and study this latter situation is not feasible within the limited budget available for the load shedding studies.Therefore,we opted to perform this analysis by running two sets of cases.One set used the first method where Kenai generation was held constant,and the other set used the second method where Kenai load was held constant. The attached plots ahead of the colored divider show the results for the cases where a fixed Kenai generation level was selected and where varying Kenai import levels were established by scaling the Kenai load.There are three plots associated with each of the generation scenarios noted above.Each plot shows the Kenai frequency response following isolation under import conditions at a Kenai import level just below and just above L\po Page 3 Mr.Afzal Khan June 21,1991 the point at which a load shedding transition would occur.The Kenai generation levels used under each generation scenario are as follows: CT-only Scenario Bernice Lake 3:6 MW Bernice Lake 4:20 MW Hydro-only Scenario Bradley Lake 1:15 MW Bradley Lake 2:15 MW Cooper Lake 1:8 MW Cooper Lake 2:8 MW Hydro-CT Scenario Bradley Lake 1:15 MW Bradley Lake 2:15 MW Cooper Lake 1:8 MW Cooper Lake 2:8 MW Bernice Lake 3:5 MW The Kenai import levels at which load shedding transitions occur for this set of cases are shown in Table 1 (attached). The attached plots behind the colored divider show the results for the cases where a fixed Kenai load level was selected and where varying Kenai import levels were established by scaling Kenai generation.As with the first set of cases,there are three plots associated with each of the generation scenarios noted above.This second set of cases assumed a fixed Kenai load level of 45 MW under all generation scenarios.This load level was established based on the output capability of Bernice Lake units under the CT-only generation scenario.For the CT-only generation scenario,Bernice Lake 3 &4 were operated at equal output levels and were both scaled as necessary to vary the Kenai import level.For the hydro-only and the hydro-CT generation scenarios,Bradley Lake 1 &2 were operated at equal output levels and were both scaled as necessary to vary the Kenai import level.The other Kenai generation scheduled in these two scenarios is as follows: S\p Page 4 Mr.Afzal Khan June 21,1991 Hydro-only Scenario Cooper Lake 1:4MW Cooper Lake 2:4 MW Hydro-CT Scenario Cooper Lake 1:2 MW (import <30 MW)Cooper Lake 2:2 MW -_Bernice Lake 3:3 MW Hydro-CT Scenario Cooper Lake 1:1MW (import >30 MW)Cooper Lake 2:1 MW Bernice Lake 3:.3 MW The Kenai import levels at which load shedding transitions occur for this set of cases are shown in Table 2 (attached). Observations Comparison of the results in Tables 1 and 2 indicates that the method used for identifying Kenai import levels at which load shedding transitions occur does have some effect on the results.This is especially the case for the stage-2 to stage-3 load shedding transition point. At this transition,the constant-generation cases indicate that higher Kenai imports would have to exist before stage-3 load shedding would occur following isolation of the Kenai.This is particularly the case for the hydro-only and the hydro-CT generation scenarios. For the hydro-CT generation scenario under the constant generation cases,Kenai imports had to be raised sufficiently high (49 MW)before stage-3 load shedding would pick up.Due to the constant generation levels used in this case,the Kenai load had to be scaled slightly above 100 MW to achieve this import level.This,of course,exceeds the present-day peak Kenai loads,and thus only represents a condition which might exist in the future.However, it does indicate that with the present Kenai load shedding scheme,higher imports will be possible as Kenai loads grow before stage-3 load shedding would be expected following isolation of the Kenai. The results do show,however,that the method used for identifying Kenai import levels has only a small effect on the results up to the stage-1 to stage-2 load shedding transition point. The results from the two methods are identical for the no load shed to stage-1 transition point.Further,the results for the stage-1 to stage-2 transition point are significantly different (5 MW)only for the hydro-CT generation scenario.Thus,this lends confidence to the Kenai import levels up to the stage-1 to stage-2 boundary. -\p> Page 5 Mr.Afzal Khan June 21,1991 The results indicate that the Kenai system relying on two combustion turbine units can import about twice as much power as it can as a totally hydro-based system and achieve the same level of load shedding following isolation.Thus,one viewpoint would be that in the future if Bradley Lake generation used in place of two Bernice Lake CT units (a historical mode of operation),larger amounts of Kenai load shedding can be expected following isolation under any given import condition.However,with Bradley generation on-line,comparable import levels can be regained by operating one CT unit in the Kenai.Thus,an alternative viewpoint is that Bradley will reduce the number of CTs which must be run on the Kenai in order to operate under some given import condition and limit the potential for load shedding to previously expected levels. After you and the Railbelt utilities have had an opportunity to review this study,please advise if you have any questions or would like to discuss this study further. Sincerely,LL)L John H.Doudna,P.E. Senior Engineer JHD: Enclosure cc:Sam Matthews -HEA ,Dave Burlingame -CEA Larry Hembree -AMLP Steve Haagenson -GVEA Dave Eberle -AEA Marty Gustafson -SWEC Apo Page 6 Mr.Afzal Khan June 21,1991 Load Shedding Transition Point 0 tol 1 to2 2 to3 Load Shedding Transition Point Otol 1to2 2 to3 Table 1 CT-Only Based System 14 MW 24 MW 35 MW CT-Only Based System 14 MW 24 MW 31 M"W Hydro Based .System 7MW 14 M"W 29 MW Hydro Based System 7MW 12 MW 19 MW KENAI IMPORT LEVELS AT LOAD SHEDDING TRANSITION POINTS (CONSTANT KENAI GENERATION SCHEDULE) Hydro-CT Based System 14 MW 28 MW 49 MW KENAI IMPORT LEVELS AT LOAD SHEDDING TRANSITION POINTS (CONSTANT KENAI LOAD LEVEL) Hydro-CT Based System 14 MW 23 MW 32 MW CT-ONLY KENAI SYSTEM.13MW KENAI IMPORT. BERNICE LAKE 3 6 4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT13.CHN |aED SOLDOTNA LISKY VOLTAGE (PO)-_---;3730000 |SOLDOTALISKYFALOUENCY (AZ)|163.000 oo $8.000 | a a - |° | !i ] a 3 ,s o | |3 |° | |3|+? \ =|- ) {Lv i [{|l |< -14.00010:30JUN191991NOLSHEDWED,CT13MW.TIME(SEC)i CT-ONLY KENAI SYSTEM.L4MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDOING ENABLED. FILE:CT14.CHN SOLDOTHA JISKY VOLTAGE (P9)[1.3000 -_--0.30000| |SOLDOTNAJISKVFREQUENCY(Hz)|63.000 ---s $e.000 | |a ||||||| __ | I --| --{ - I | b-4 | | -_-| | -oom | | - 1 _ | pointy |- ) i [|ov |||I !!230JUN19199110STAGE1LSHEDWED,70.000CT14MW.46.00014.00012.000TIME(SEC)4.00002.0000 i 1 CT-ONLY KENAI SYSTEM.23MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT23.CHN SQOLDOTNA-LUSKV VOLTAGE (Pg)J13.3000 0.30000 | bereoo SOLDOTWALISKYFREQUENCY.(HZ)| ee es Oe es ee ee |: 'om , , a L |: |"7 a j 4 LE |IE | | | j - Z |i |T a | a - \ L.\ XN J 1 I I !3 33110JUN191991STAGE1LSHEDWED,CT23MW.TIME(SEC)CT-ONLY KENAI SYSTEM.24MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE.zaTRIPDAVESCREEK-UNIVERSITY J15KV W/O FAULT.mo fa] WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.em FILE:CT24.CHN 4)a an ”a)zedBe a a |SOLDOTNA 1)SKV VOLTAGE (PU)|&.: [7.3000 -="s 6.30000|=SOLDOTNA115KVFREQUENCY (HEI J os163.000 -_---*Se.oco |N {a |||1 {||3 5 I 13 J " |2 |s {2]4: |3 -]i !g38LL|i: q z9 |g & = i 2 |3 =ods| oe|3 =2 { a \ti X 7 eo1lWI!!I !$ if CT ONLY KENAI SYSTEM.34MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT34.CHN __SOLDOTRA:1]SKY VOLTAGE {0}{7.3000 =="T_9.30000| 163.000 -SOL D2TEA_LSKY EMERY {HE ---*sel |1 Jl {J {i |3 onl |° ; 4 |"Tr j _ LE |3"Ts | | | a 3 a a | 4 \:={% { -\- Cy l Is |i g 18.00010.00014.000TIME(SEC)JUN19199110:32STAGE2LSHEDWED,CT34MW.it CT-ONLY KENAI SYSTEM.35MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE.TRIP DAVES CREEK-UNIVERSITY115KV W/O FAULT.WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT35.CHN SOLDOTNA11SKV VOLTAGE (Pg)[i.3000 --¢6.30000| bersss tinh _---$@.000 | 1 ry ot ||||1 { | |a | | _a | . | 4 | -- | - | _ | Lo | - | = | _ ) a |Z | =\- fe t 1 ||l |20.00012.9004.000036.00014,00018,000TIME(SEC)10:33JUN191991STAGE3LSHEDWED,CT35MW. HYDRO-ONLY KENAI SYSTEM.6MW KENAI IMPORT. BRADLEY LAKE 1 6 2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY LISKV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY06.CHN L SOLDOTIOLISKYVOLIAGEsP9)11.3000 _0.30000 | SOLDOTIALISKVFREQUENCY (HZ)163.000 -e 58.000 | a es 0s ee ee 3 4 a |g |"1s L |a|= 4s|- L I 3 \"Tes L |me |3 a i eo\| a |3 !ws {3 |3 = \ & \||a {{:10:46NOLSHEDJUN191991WED,HYO6MW.TIME(SEC)if HYDRO-ONLY KENAI SYSTEM.7MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY07.CHN |SOLDOTWA LISKV VOLTAGE (Pc)11.3000 _0.30000 | bass nn os 50.000 | rT ft TT 3 = |”% : I 2 |= i |i )- i _ |- |3 |4 i =|le / s 7 i 1 \3 - |4 \3 =)con re) ) |J a !J $JUN19199110:46STAGE1LSHEDWEO,HYO7MW.TIME(SEC) 20.HYORO-ONLY KENAI SYSTEM.13MW KENAI IMPORT.HYDRO-ONLY KENAI SYSTEM.14MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 6 2 ON-LINE.2n BRADLEY LAKE 1 &2 AND COOPER LAKE 1 6 2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT.ba i)TRIP DAVES CREEK-UNIVERSITY 11SKV W/O FAULT. WITH UNDERFREQUENCY LOAD.SHEDDING ENABLED.em -WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY13.CHN ”)FILE:HY14.CHN n a "6ba& "a aSOLDOTIO"LISRV VOLTAGE (PO);Fol SOLDOTNA115KV_VOLTAGE.(PU)]==TF 5.30000|=[i.3000 ===©0.30000|-_$QLDOTNA_L1SKY FREQUENCY (Hz)al |SOLDOTWA_115KV FREQUENCY (Hz)| 58.000 |ed]|63.000 $8.000| rt Te & 3r-3 4:= +3 =J 4:L__ ke oIL i: 03324s =_ z3ou e@ +:=- 3'em eo -am 3 2 =_ -bo =4 |s l 4010JUN191991STAGE2LSHEDWED,16.000HY14MW.a634.0000.00006.000010.000TIME(SEC)4.00002.0000 HYDRO-ONLY KENAI SYSTEM.28MW KENAI IMPORT. BRADLEY LAKE 1 6 2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY26.CHN |SOLDOTIA"11SKY VOLTAGE (PO)[4.3000 --¢"0.30000|--SOLDOTWALISKYFREQUENCY (82)J163.000 -_---+4 58.000 | ||j |{i J I J 3 8 L g /s | |3 |be} Lo 1 i ,2 Lo |3 \b} |3 |s {3_-ts i | es) |3 --8 7. ] Z r g a P)||Le |!:JUN19199110:38STAGE2LSHEDWED,HY28MW.TIME(SEC)HYDRO-ONLY KENAI SYSTEM.29MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. :FILE:HY29.CHN SOLDOTIA LISKY VOLTAGE (PU?J {1.3000 --_--«@.30000| I SOLDOTNA_]}SKV FREQUENCY (HZ)163.000 +$e.000 |20.00046.00012.00028.00023910JUN191991STAGE3LSHEDWED,HY29MW.TIME(SEC) HYDRO +CT KENAI SYSTEM.13MW KENAI IMPORT. BRADLEY 1 &2,COOPER 1 &2 AND BERNICE 3 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY-CT13.CHN $1.3000 S2LDOTMA”1136Y VOLTAGE (PO)-_---0.30000|Lawes S0LPOTIO L135Y_EROUENCY {Hz}---58.000 |CT TT ry TT 3 e Zz 7 2 |3 {7s L a i - |_ {2) La - { a |_- |; be \ - | s \3 \ . a \ 4 !!1)!!l |I 3 20NOLSHED10e «10.000TIME(SEC)2.0000JUN191992WED,HY-CT13MwW.bi HYDRO +CT KENAI SYSTEM.14MW KENAI IMPORT. BRADLEY 1 &2,COOPER 1 &2 AND BERNICE 3 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY -CT14.CHN 11.3000 -_---0.30000| SOLDOTNA_LISKY FREQUENCY.(AZ)J 163.000 ----*$a.o00 | rT fT TT rT 3 cme |at | Lo |_2 |P a \ Z | 5 |_ |- | | ! a |= l }3 \ < a \a | !!1?||I {|$18.00016.000ie.TIME(SEC)10:20STAGE1LSHEDWED,JUN191991 HY-CT14Mw, HYDRO +CT KENAI SYSTEM.27MW KENAI IMPORT.HYDRO +CT KENAL SYSTEM.28MW KENAI IMPORT. BRADLEY 1 &2,COOPER 1 &2 AND BERNICE 3 ON-LINE.Ma)BRADLEY 1 6 2,COOPER 1 &2 AND BERNICE 3 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 11SKV W/O FAULT.ean TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.om WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY¥-CT27.CHN 4 FILE:HY¥-CT28.CHN a ae 28ZeBe 2] a|SOLDOTIOLISKYVOLTAGE (PO)Fy :SOLDOTIA_LISKY VOLTAGE {P9}11.3000 ===T 0.30000|&[i-3000 aT 0.30000| =__$2LDOTIA_LLSEY FREQUENCY (Hz)J -«SOLDOTWAJISKVFRZQUENCY (HZ)J 163.000 ----*58.000||Fe3-000 ------s_58.000 | 'H|{jl ||||{i 3 Oo |{}!|{{|J |5: |va |i =$m)LE +:|s |: |g |g =_j*=.|2 {2 L \i |i |”j - |3 |3 =*=4.]7 | rT)|a |g-4§2 74 43|: Lo |g #{3 Ty i T |t L | "|«6 -"Tl « a -ol + ]73 8 =\_é =\4s. N\'N -”oe!{an 1 e |I kW J |||3 10:19JUN191991STAGE2LSHEDWED,HY-CT28MwW.TIME(SEC) HYDRO +CT KENAI SYSTEM.48MW KENAI IMPORT.HYDRO +°Cee eee a AND BERNICE 3 ON LINEBRADLEY1&2,COOPER 1 &2 AND BERNICE 3 ON-LINE.BRADLEY 1 &2, -. TRIP DAVES CREEK-ONIVERSITY 115KV W/O FAULT.o a TRIP DAVES CREEK -UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.here ©)WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY-CT48.CHN 4 FILE:AY-CT49.CHN aN *5Be a?) a SOLDOTWA 'LISKV VOLTAGE (Po)Fy :SOLDOTWA LISKV VOLTAGE {P9)-"S-"=FT 0.30000|&[1.3000 -==©0.30000| SOLDOTIA LISKY FREQUENCY 2){SOLDOTWA115KVFREQUENCY (HZ)---F 58.000|be {63.000 ----t 58,000 | !{}!|1 j 3 5 \Py |{|'{|3 io oi}- |g 2 | |78 -l Be oUL :|=i 2 |18 r | |3 |3 o|332Tee |F ; I g &3- le -oe\ |i 4:= 3\42:= -- =J J le ||l by !WED,JUN19199110:17HY-CT49MW.STAGE3LSHED14.00018.000TIME(SEC) 45MW KENAI LOAD.CT-ONLY SYSTEM.13MW KENAI IMPORT. BERNICE LAKE 3 6 4 ON-LINE. TRIP OAVES CREEK-UNIVERSITY L15KV W/O FAULT. WITH UNDERFREQUENCY LOAD SREDDING ENABLED. FILE:CT13S.CHN [1.3000 =9.30000|{SOLDOTIOLISKYPRrouENCY (Hz)163.000 c7_ooo*$8.000 | ||f ||||||3 |ee 7 | |. ,mi a \ _ | Lo 3 |bs} a | } ; |io | | a |6. \ =| } L tet |4 'a .310.00014.00018.000TIME(SEC)08:12JUN211991NOLSHEDFRI,CT13S-MwW.45MW KENAI LOAD.CT-ONLY SYSTEM.14MW KENAL IMPORT. BERNICE LAKE 3 &4 ON-LINE.2aTRIPDAVESCREEK-UNIVERSITY LISKV W/O FAULT.z Gd)WITH UNDERFREQUENCY LOAD SHEDOING ENABLED.bade 0} FILE:CT14S.CHN n an Ae fl*oZtBe WY "4VOLTAGE{PO}J ° {1.3000 SouDoT LUSK --=-=©4.30000|me =SOLDOTNA_1]SKV FREQUENCY (HE){i[63.000 ----*58.000 |ry) i a !||J J |3 g & |3 0 =4: |3 j da=: |a_.': g|3 =4:|: |3 & oe L mi |i_-|: a }_ | L 3 = \@ /|{,1]l !I {|: if 45MW KENAI LOAD.CT-ONLY SYSTEM.23MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-ONIVERSITY 115KV W/O FAULT.WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT23S.CHN |SOLDOTIO,LLSKV VOLTAGE.(PU)|$3.3000 --¢"6.30000|SOLDOTIA215KVFRZOUENCY (Hz)}63.000 4 50.000 |ae 0 ee ee ee ee ee 3 = |* 4 L |3 |7s a | 4 L |3 |"Ws =I -| a |3 Ty a | 4 |3-'pabd \ _ \4 ° l be 7 {|I g 14.00008:24JUN211991STAGE1LSHEDFRI,CT23S-MW.TIME(SEC)45MW KENAI LOAD.CT-ONLY SYSTEM.24MW KENAI IMPORT. BERNICE LAKE 3 6 4 ON-LINE. TRIP DAVES CREEK-ONIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT24S.CHN SOLDOTIOA LISKY VOLTAGE (PO) {1.3000 SOLDOTIALISKYFREQUERCY (HZ)_---e 6.30000| { [63.000 $8.000 | 1 weeeeiaieaele{I ||i 06:14JUN211991STAGE2LSHEDFRI,CT24S-MwW.TIME(SEC) if 45MW KENAI LOAD.CT-ONLY SYSTEM.30MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 11SKV W/O FAULT.WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT30S.CHN |SOL DOTNA-115KV VOLTAGE (P11.3000 u --¢9.30000|--SOLDOTIALISKYPREQUENCY (Hz)J163.000 -4t 58.000 | I ry 7 J I I ||{3 me -_| |3 |"7 | =- | |3=i |by _ | | a 3 |}° = | | a : \ 7 \ -i ) a <a os fe 10.00034.000TIME(SEC)06315JUN211991STAGE2LSHEDFRI,CT30S-MW.4SMW KENAI LOAD.CT-ONLY SYSTEM.JI1MW KENAI IMPORT. BERNICE LAKE 3 &4 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV #/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:CT31S.CHN SOLDOTNALISKYVOLTAGE (P9)[2.3000 -_-=0.30000 {SOLDOTIALISKYFREQUENCY (HZ)_} 163.000 o-----_*#58.000 | |if (1 l |I |t 3 {a | g |4 -- ) - | L |i |s |oe 4} |3 | e - | cae | |3 =|4: =NX 4 ?be [ec ty ft 4 2 14.00006:15JUN211991STAGE3LSHEDFRI,CT31S--MW.TIME(SEC) 45MW KENAI LOADS.HYDRO-ONLY SYSTEM.O6MW KENAI IMPORT.BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE.TRIP OAVES CREEK-UNIVERSITY 115KV W/O FAULT.WITH UNDERFREQUENCY LOAD SREDDING ENABLED. FILE:HY06S.CHN {_SOL . [riee DOTA LISEY VOLTAGE (PO)---;sar -_SOLDOTIALISKYPRZOUERCY (Hz)163.000 ---4 $8.000 | |TT l rT |3 g a l g |13 a |g |Ts as 1 det= g-oa L ||}3 LE ]: |* L z |7° \3 =,;_ 2 \oO \15:28NOLSHEDJUN201991THU,HYO6S-MW.TIME(SEC)45MW KENAI LOADS.HYDRO-ONLY SYSTEM.07MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 6 2 ON-LINE.2 QTRIPDAVESCREEK-UNIVERSITY 115KV W/O FAULT.Gl WITH UNDERFREQUENCY LOAD SHEODING ENABLED.om FILE:HYO7S.CHN ” «atl a Aa Qo Qi]12BH W 5 SOLDOTIA LISKY VOLTAGE {P9)|zo [4.3000 =="9.30000|= SOLDOTIALISKVFREQUENCY (HZ)j =163.000 $e.000 |”) Cer-TYJro7T 4 3 5 a |3 =x "|=|a |g =4.|a a {ji |"a Lo 3 |7 G|23 --1 6 "g|g & .|43 {3 =(4: " }3 =le| \3 =-¢&\* ) l [At 2 45MW KENAI LOADS.HYDRO-ONLY SYSTEM.11MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD.SHEDDING ENABLED. FILE:HY11S.CHN 6.30000 | $8.000 |22.0004.000014.00015:26JUN201991STAGE1LSHEDTHU,HY11S--MW.TIME(SEC)45MW KENAI LOADS.HYDRO-ONLY SYSTEM.12MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-ONIVERSITY 115KV W/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY¥12S.CHN SOLDOTWA LISKV VOLTACE (PU)[1.3000 -----*6.30000| |SOLDOTNA 115KV FREQUENCY (f21 | 163.000 ----_*50.000 } rf 3 _-I - ] \_B /s a _ | |3Loeafa| ) a (_- e] ( - -_- °{3 -je \}-- \ 'XN |!>hae |¢14.00030.000TIME(SEC)15:27STAGE2LSHEDTHU,JUN201991HY12S-MwW. 45MW KENAI LOADS.HYDRO-ONLY SYSTEM.18MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER LAKE 1 6 2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY18S.CHN =SOLDOTIAJISRYYOLTAGE (PO)11.300 -="§,30000|L-SOLDOTHALISKYFREQUENCY (Hz)163.09 50.000 | a ee Oe - \| | a |g |3 L ) | | _ |a: i 3 a | \ a |3 |C) - I - | \3a|+3 14 = i - y)Poof i-"tf 2 16.00014.00018.000TIME(SEC)6.0000JUN20199115:24STAGE2LSHEDTHU,RY18S-MwW.45MW KENAI LOADS.HYDRO-ONLY SYSTEM.18MW KENAI IMPORT. BRADLEY LAKE 1 6 2 AND COOPER LAKE 1 6 2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDOING ENABLEO. FILE:HY19S.CHN SOLOOTIA LISKY VOLTAGE (P90)Laas --«@.30000| SOLDOTIOALISKVFREQUENCY (FZ)163.000 ----*$e.000 | J |}|{||I |3 3 La s 3 y = g 4 a 3 g oe =e 3 : / ": 3 =« 1 3 18:24JUN201991STAGE3LSHEDTHU,HY19S-MwW.TIME(SEC) 4SmW KENAL LOADS.HYDRO +CT SYSTEM.22MW KENAI IMPORT. BRADLEY LAKE 1 &2,COOPER LAKE 1 &2 AND BERNICE 3 ON-LINE.TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH ONDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY-CT22S.CHN I ___SOLDOTNA.LISKY voLTAG[i300 VOLTAGE {P9)==T7.30000|{|___sOLDOTWALISKYPRECURNCY sz)|163.000 58.000 | re 2 ; Lo | a |R|be 5 j | a 3 |5 | | | a |3 |oo a | | |3 J =\_ b) |a |l e 08:41JUN211991FRI,STAGE1LSHEDHY-CT22SMW.TIME(SEC)4@5MW KENAI LOADS.HYDRO +CT SYSTEM.23MW KENAI IMPORT. BRADLEY LAKE 1 &2,COOPER LAKE 1 &2 AND BERNICE 3 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY-CT23S.CHN SOLDOTIA_LISKV VOLTAGE (PO)| 11.3000 --¢0.30000| SOLDOTIO._LISEV FREQUENCY (Hz)J 163,000 -_--e 56.000 | 1 ||l ||if i |3 | - | a |8 |* | L |BR |- | |3 / _.|_ / a \y i ! =\4 ) I a !|1 {2 10.00024.000TIME(SEC)2.000042STAGE2LSHEDFRI,JUN21199108HY-CT23SMW. 45MW KENAI LOADS.HYDRO +CT SYSTEM.31MW KENAI IMPORT. BRADLEY LAKE 1 6 2,COOPER LAKE 1 &2 AND BERNICE 3 ON-LINE."<aTRIPDAVESCREEK-UNIVERSITY 115KV 4/0 FAULT.™GlWITHUNDERFREQUENCYLOADSHEDDINGENABLED.°G FILE:HY-CT31S.CHN n aH an aa)E etBa =”) E__SOLDOTIA LISKY VOLTAGE (PU)|: --fT 0.30000|=SOLDOTIALASKYPRBOUENCY (HZ)|&----*$8.000 |+||} ”rr re Tt |"g J ,23 |3 |s !i |z |4 3 o|ga |$3g& eo|| |i |7. 3 bd f .2 \3 '* ) l ||I 2 45MW KENAI LOADS.HYDRO +CT SYSTEM.32MW KENAI IMPORT. BRADLEY LAKE 1 6 2,COOPER LAKE 1 &2 AND BERNICE 3 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:HY-CT32S.CHN SOLDOTIA LISKV VOLTACE (P9}}1.3000 --=-¢9.30000| {SOLDOTNA_LISKY FREQUENCY (HZ)| [63.000 o-_-*$8.000 | rTP.or ¢Yr st | | | | , a a | | - | - | a ,_ _|4 ( Lo }a \ i. C 4 \ ( J '_ PB] I |a |i !i 247JUN21.199108STAGE3LSHEDFRI,HY-CT32SMwW.,32.00030.00014.000TIME(SEC)8.00004.0000 cay o> ore ro)maa”POWER TECHNOLOGIES,INC.ONE SIERRAGATE PLAZA SUITE 3408 = ROSEVILLE,CA 95678 916 783-3566 TELEFAX 916 7832086 TELEX 145496 June 25,1991 Mr.Afzal Khan Alaska Energy Authority P.O.Box 190869 Anchorage,AK 99519 Dear Afzal: Re:Revision To June 13,1991 Kenai Import Study Letter Report We presented the results of the Kenai Import Study at the June 14,1991 TCS meeting in your offices at Anchorage.After review of this study,Dave Burlingame observed that the differential between the Anchorage export (which was part of the data provide by CEA)and Kenai import as measured at Daves Creek appeared too small for some of the conditions. This differential is a function of the load connected to the system between University and Daves Creek;data which had not been provided. Dave Burlingame was to review CEA's SCADA information for these historical conditions and provide us with data for the loads between University and Daves Creek.Depending on the results of this review,we were requested by the TCS to rerun cases,as necessary,which better account for these loads and thus have Kenai import levels which are closer to the historical situation. After review of CEA's SCADA information,Dave Burlingame advised that the three winter and three spring cases needed to be revised to show a larger amount of load between University and Daves Creek.He reported that the summer cases as originally reported appeared reasonable.Therefore,we have prepared new power flow cases for the winter and spring conditions and have rerun the dynamic simulations associated with these cases.In rerunning the dynamic simulations,however,we only ran cases with the load shedding relays in service in the Kenai.The procedure and disturbance used in these new simulations are the same as used previously for the base case dynamic simulations.The power flow and dynamic simulation results for these new cases are attached. CORPORATE OFFICES *1482 ERIE BOULEVARD «PO BOX 1058 ¢SCHENECTADY,NY 12301-1058 ©$16 374-1220 \p> Page 2 Mr.Afzal Khan June 25,1991 Summary of Results As was done in the first report,the results of the new dynamic simulations are summarized in the following table.This table shows the number of Kenai load shedding events and final frequency for both the historical situations with CT generation and the same Kenai load/import condition with Bradley generation replacing all of the Kenai CT generation.An asterisk is used to denotethose situations where the number of load shedding events and the final frequency changed compared to what was shown in the previous report. Summary of Cases With Kenai Load Shedding Relays In Service With CT Gen With Bradley #Load Final #Load Final Shed Freq Shed Freq Case Events (Hz)Events (Hz) Winter 1 5 59.6 10 60.2 Winter 2 10 60.6*10 60.2* Winter 3 o*59.3 5*60.2* Spring 1 10 60.8*10 60.3 Spring 2 10 60.3*10 60.1* Spring 3 5*58.8*10 52.8* From review of the above information,it can be observed that the number of load shedding events only changed for the Winter Case 3 condition (both with CTs and with Bradley)and for the Spring Case 3 condition with CTs.For the Winter Case 1 condition,the revised cases indicate that no load shedding occurs in the Kenai for the situation with CTs,and five load shedding events occur for the situation with Bradley.These are down from two and ten load shedding events,respectively,compared to what was shown by the previous study.For the Spring Case 3 condition with CTs,only five load shedding events occur in the new simulation compared to ten events shown in the previous simulation. The final frequency,where changes occurred,was significant only for the Spring Case 1 with CTs (1 Hz higher)and the Spring Case 3 with CTs (0.9 Hz lower). p> Page 3 Mr.Afzal Khan June 25,1991 Generally,the change in Kenai imports resulting from the representation of larger load amounts between University and Daves Creek did not have a significant effect on the results. Based on the small system response differences shown by these new cases,the observations drawn in the previous study report are still valid. ) Please advise if you have any questions concerning these revised cases. AAR John H.Doudna,P.E. Senior Engineer JHD: Enclosure ce:Sam Matthews -HEA Dave Burlingame -CEA Larry Hembree -AMLP Steve Haagenson -GVEA Dave Eberle -AEA Marty Gustafson -SWEC BERNICE BERNICE SOLDOTNA 9990 Hop 7 2.6 9988 9989 SOLDOT1G 0.0 rtd 4.7 me H4.9 49H _.¢__flo.o ay""*0.0 ns 0.9 =2.6 "Ss Yo.0 0.0001 ™Daves?oa 1.0272.3 2012 9986 iw 24.9 4.6 =29.9 SoLp Svs ee pes 2 o§--flo.2 °&-ay is---of4.28 5$a”0.0 ace 29.2 0.0 4.2503 en egosoofSsFyzS z.2 ORTZ CR7,4 a 1.3i-6]7.707 ¢8 9987 TSE 1.014 SKI HILL =25.4 25.98-20.5 29.4 o4 0.6 "1.50123 ba 1.025 LAWING SKI HILL©2,009 "25.8 ahd 30.2 QRTZ CR ¥1.0249993-24.8 ac]Lond min TESORO -l|.$a a)ide t 1 1 ' 'coop LK cla 1.026MFad'9991 IT =24. 46 ' 5 'wpe man ry yy oN=se ' _'©:i] t t A ' ' t BEAVR TP 0.967 70 p W32.2 on om 80 BEAVA CR ea "jo ANCH PT Yi 0.96778wet8 NIN ala ot a DIAM RDG Ti 0.9599965mh34.4 wie %"Ie=Regitis23©3.4 _oe a FRITZ CR BRAD LK 9997 0 bwwww enna nd 9h -110.030.0 -1.6 =0.4 S ewww mere mnmmweeoenwoweeowonncsne --9§---+19 92o-Be$-i-4 0.0 5°*0.4Yo.959 ia,000"-734.4 0.0 WINTER 1990.CASE 1.41MW ANCH EXPORT,29.2MW KENAI IMPORT. BERNICE LAKE 3 &4 AND COOPER LAKE 1 &2 ON-LINE. ub MON,JUN '24 1991 09:12 -KV:s69 ,£138 .6230 DAVE Svs 986BERNICESERNICESOLDOTNA HOPE 0.0 9968 (°°?9989 soLporic 0.0 op 3.0 me -20,0 20.18 loo qy?*®0.0 +-e.a 7.0 "2 o.o 0.0001 %pavesocR |ale dee9.0 0.988 986 thes 34.9 0.0 "31.sou Svs ojo vlba0,0 =ctx alor=]=-Lod4.92.6 8 +f 0.0 owe "20.2,"|!' 0.0 qetes go begetSObe=é z 3 728 QORTZ CR7,4 o 4.4 1.617.7°°6.8 9987 1.656 oe a 0,975 SKI HILL =?5.4 25.81-20.5 33.4 e4 =r.1.00.9 ' 9996 022 LAWING 25.9 oRT2 cr "EY 1.022 9993 24.9 wie rm-"|o sloTESORO="J!7 69 TIT i a t 'mln 'coop tx gig 1.024"iv '75 9991 mit =24.2 934 '3 r)ny ve,KASILOF .i%1.006 <=lan '14 The -30.7 SOLDOTNA yw aNanols'jo "levy@®SS Pell =a !als ajo'21.0437 f)8s 'KASILOF t Lew ewewe ee ee ee ey ' BEAVR TP}0.963 70 31.2 oe ale ao BEAVR CR od ANCH PT oI™ tin bs bitalles one ANCH PT DIAM RDG "7 2.017 9965 ajl--31.0od(a)Pry ole an 21,5)71!zs 8 3.2 a FRITZ CR BRAD LK9997500 9.1 $12.3 @)5.5 $4.0 13.8 3.7«<-15,3 13,5 'S 12,3nnPyzo-BeS L.6][-4.2 1.7 v<4.0 @)go".0.40;.021 1.036ao-30.-28.7 a WINTER 1990.CASE 1B.41MW ANCH EXPORT,29.2MW KENAI IMPORT.i BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-<-LINE."hu MON,JUN 24 1991 11:29 KV:S69 ,£138 ,@230 16.00012.000WINTER 1990.CASE 1.41MW ANCH EXPORT,29.2MW KENAI IMPORT.WINTER 1990.CASE 1B.41MW ANCH EXPORT,29.2MW KENAI IMPORT. BERNICE LAKE 3 6 4 AND COOPER LAKE 1 &2 ON-LINE.za BRADLEY LAKE 1 &2 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT."Gl TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.em WITA UNDERFREQUENCY LOAD SHEODING ENABLED. FILE:WINIA2.CHN n FILE:WINIB2.CHN aQaidwe<[e)anz>B H |SOLpori-1SeyyoLtace 1 36 re LiseSOLDOTNA-{P0)SOLDOT'!SKV_VOLTACE (Pd)11.3000 ===F 0.30000|0 [7.3000 -==9.30000| SOLDOTNA LISKV FREQUENCY (HZ)|o||SOLPOTNA LISKV FREQUENCY (HZ)162.000 --*"57.000|fa|[62.000 ---*_57.000} 7){|J |1 |{||J 3 KH {|{|{|||{ *G=43 _ | __f _] |-- |i _=ga ae |g 2 - |g & =le 4 Ld| =-|3 _ R |]° |3Z(--[8 _ be l !a I !I t l 2 !16:21JUN241991BRADLEYW/LOADSHEDMON,4.0000€.00006.000010.000TIME(SEC) DAVE SVS 9e6BERNICEBERNICESOLDOTNA HOPE 0.0 99ee 9990 989 SOLDOTIG 0.0 =o 90.0 af 0,4 O.«h os fle.0 7}O-s5 'me 13.0 2.7 "S Yo.0 o.000 1 %paveseck =f IS dev9.9 0.996 9986 nt =37.5 9.5 33.9 tt Svs ao Nin ba 0,0 =-ain =olor==-Sd °1855 ne +f 0.0 we $9.2 !' o.0f >Wane &900.0.0 ie -a <oe 23.3 ORTZ CRi750868+03 9987ect: oc 648 0.998 SKI_HILL =29.0 22.6}-25.8 -33.a4 0.3 1,192.0 - 9996 1.013 LAWING Sxr HILL?'mes'QRTZ CR 1.026-H 9993 28.0 n a Cn)ioe)Ale" 'alo wlooe'"6 ltTESOROse0.997 '' 69 D 34.0 ' T a 1 4 'it 'i i 'Slei'coop LK SIM 21.019<4 rt rl 999)Ajo -27.,3,t o '929 '2 4ub.KASILOF &%'aa i 44 7 'atv oe '=11abadt ola ola '”H aio ala;'rt 8 'a '§ 'HireneWeeetateiaetBEAVRTP,0.953 t 70 Ln "34-6 ' ae ' om ( ' ¢ i] 80 ' BEAVR CR ' ' t ie 'ANCH PT SIV 0.953 ' 7S the -4 ' bel fat 'Nis t-”' ' ' ' ' t ' ' 'e 'oa OIAM ROG Si 0.945 :9965 tr 38.0 'nie ' %|4d"3 11,3 '$8 3.3 'zs =}' a t°' ' FRITZ CR \BRAD LK9997'$00 ne |ee ==2)0.0 <1.5 0.4 [4on we ween nna wanaeweasaanccewewcoucond|«op5-0.0 ne Bef 1.8 0.0 :-4Yo.945 0.000="38.0 oO. WINTER 1990.CASE 2.46.4MW ANCH EXPORT,34.2MW KENAI IMPORT BERNICE LAKE 3 AND COOPER LAKE 1 &2 ON-LINE. MON,JUN 24 1991 09:20 KV:669 ,6138 ,@230 DAVE SvS 986BERNICESERNICESOLDOTNA °9988 a 9989 SOLDOTIG 0.0 Hose7)me 19.4 19,5)os flo.e ys?"0.0 're 7.7 6.6 4 yo.o 0.000 +™pavesockR {xo 1,0250.0 -994 9986 rho =27.8 0.0 -35.1 sou Svs Cy er oobe0,0 =sla alo[=]=-wu4.88 $a"+f few e)ne 20.2]"|!' 0.0 }e--4.15 es gn go0.00.0 tal a a 9.4 7 "1 osrz om1.517.852 -Pease Zo8 0.982 SKI HILL -29.1 29.78 -25.7 36.7 eo 1.5 3.03.2 9996 -1,923 LAWING SKI HILL «&-28. 98 *orrz cr Y%”1.02 -9993 27.9wnaioaniaalewilemwmt- Tesoro lt 0.901 ' 69 tha 36.8 t Li } \aioCcooPLKslo 1.026aWIS"yw 999 =(0 27.2 024 '< =1 RSTLOF RR .'ed L a a pe'olo Qo ' t } [ibea moeweweeeabnwwwneny a BEAVR TP 0.968 70 34.5-- Dict olen 80 BEAVR CR a ANCH PT «;015 75 D 34.7 " So + DIAM RDG "/©@ 1.016 9965 slo 34.8 wIio &oo ne me 12,2}71° a $8 3.128 a FRITZ CR BRAD LK99970 5.3 0.03.7 --0§---4 0.0 11,6 3.2 «ow 33.2 133 oS 16,6 dd)ae ra $1,5]/-3.5 1.0 <5.6 1 5°9.3):,020 1.032en34.4 32.8 ;WINTER 1990.CASE 2B.46.4MW ANCH EXPORT,34.2MW KENAI IMP.I BRADLEY LAKE 1 AND COOPER LAKE 1 &2 ON-LINE.'MON,JUN 24 1991 11:35 KV:869 ,6138 ,@230 WINTER 1990.CASE 2.46.4MW ANCH EXPORT,34.2MW KENAI IMPORT BERNICE LAKE 3 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV #/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:WIN2A2.CHN SOLDOTNA115KV VOLTAGE (PU)}2.3000 --+"4.30000| SOLDOTNA1]$KV_FREQUENCY {HZ}|62.000 o---__-*57,000 | a |rT TT TT g 4 E |[2 |bj |3 |"Ts a ti h4|a |3 |Te a ||3 J 2 ||_-2| | |3 +6| 3 _.2ie 3 _.oe i)we |2 16:22JUN241991MON,HISTORICALW/LOADSHEDTIME(SEC)WINTER 1990.CASE 2B.46.4MW ANCH EXPORT,34.2MW KENAI IMP. BRADLEY LAKE 1 AND COOPER LAKE 1]&2 ON-LINE.vaTRIPDAVESCREEK-UNIVERSITY 115KV W/O FAULT.¢[¢9]WITH UNDERFREQUENCY LOAD SHEODING ENABLED.ae >} FILE:WIN2B2.CHN 7) 29=Oatz35 7z |SOLDOTNA L15KV VOLTAGE {PU}2x [1.3000 ==0.0000|Q SOLDOTWAJISKYFREQUENCY {HZ)s162.000 ----*$7.000 |a ||{|J |||343 -< I 3 |Pd i-A | - \373 o 33w 3 & o =e g .s 3 Lo of /;7 8-ww - ||2 DAVE SVS 986BERNICEBERNICESOLDOTNA HOPE 1.2 9986 "re 9989 SOLDOT1G 0.0 49= 1 994 Q)-2:31--#--3.2 4 4,6 4.6 6s fis.9 ep)0.0 !re "1.5 -0.3 Ss pii.3 0.0001 ©pavecR =!Sie 2 jes 1.022 9986 ub ba1=30.7 SOLD SVS a e 0,0 38 ro sin alo°-}-0§-uo wwe "°[3-4 ao$_m @ 0.0 aa Two2 3.4 4.7--Zz an o00.0 2.0 -i <r=) a a 26.7 8,7 »2.4 ORTZ CR 2.0 Caer So 9987 1.65"o°8 1.019 "| ser run =24.8 :25.29=20.4 =30.3 ry 1e2 -3.683.1 "i 1.030 LAWING SKI HILL 2 'aw!'ORTZ CR 1.02¢r=)'999 F -25.9 i ala wileTESOROto1.028 'io 69 tity -30.3 ' ;' t ' 'i '}at'coop Lk ¥|.t 1.030 we \9991 AIT 25.2P'o 'gan '°t 'KASILOF &' |o my '74 hy 'ye oNalan=:any ' |:ie a'eio'' 'a \' '' Lew wewnwoewe e ' ' a ' ' ' § ' ' ' t & 5 : ANCH PT 7 $ =1 +i] -4 a 4 i 4 ' ' ' 'had tawr)DIAM RDG Zin 0.963 19965hs35.5 ' Gd Bd ' &-"2 '2g -__egiz.t.'za 8 ' a ' ' a FRITZ CR \BRAD LK9997\$00 nen |ON See AL0.0 -1.7 -0.4 «<oN aes |Snes meee |CoPE*)no-5e 1.7 0.0ee040.962 0.000oo 35.6 0.0 BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE.We WINTER 1990.CASE 3.43.5MW ANCH EXPORT,30MW KENAI IMPORT.ifi MON,JUN 24 1991 09:30 KV:£69 ,€£138 ,6230 DAVE svsBERNICESERNICESOLDOTNA nore 0.0 9908 r.9989 SOLDOTIG 0.0 |=de ==a97|'@Qe-24 >Ss -22.8 22.9 S ffo.e_7)0.0 : re -9.8 9.0 i 3 yo.o 0.000 r)bedcoSaaltinae3283SOLDsvsa0.0 -32.8 Ss «ys r bd 0,0 o hn weo- be om -Wo?3.4845 a"0.0 ae Regao-20.0 ie 4.955 93 goo.-3¢-4 ==0.0 FY Ss 20 QORTZ CR8.7 2 8 w4.3 9987 2.118.683 ¢,7tefahetego8 24.5 24.99-20.40.954 SKI HILL ;-34.9 *"2.2 O.1H0.7 . Tas?9996 wiLA1,08 LAWING o "26.J "@bi990rtenedzyat.3 oRT2 cR"4 2.014 "1°9993 26.0 "ie oetHo Wiewsotpotna"3 =ay7a0.983 9992 ' TESORO ale 3333 ' 4 § 'tad'COOP LK wjN 1.017Handhand.4 ' i] 'yw oN ' 're Ale 'ola ela ' '85 'KASILOF , bee eve voewe em wee "74a BEAVR TP)0.947 70 L -32.3 ar alin eoBEAVR CR ANCH PT %2,004 75 -6 [Eee % ad ' DIAM ROG "I?1.0079965wit-31.5 cmd Lae) CJ . uo -_.we=o 12759)7)! za 3 3.8 a FRITZ CR BRAD LK 9997 500 14,2 oS 16.67.3 "<$.8 @)17.2 4.6 &x 16,9 19,2 os 18-7])ae:5 1.71/-5.0 3.0 ed 5.8 ok o-4Va.o13 1,031=--30.9 -28.7 20ealOUPwhereWINTER 1990.CASE 3B.43.S5MW ANCH EXPORT,30MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE. .MON,JUN 24 1991 11:42 KV:569 ,6138 ,@230 WINTER 1990.CASE 3.43.5MW ANCH EXPORT,30MW KENAI IMPORT.BERNICE LAKE 2,3 &4,COOPER 1 &2 AND SOLDOTNA ON-LINE. TRIP DAVES CREEK-UNIVERSITY L15KV #/O FAOLT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:WIN3JA2.CHN Laas SOLDOTNA LLSRY VOLTAGE {PU}---<saaLaasSOLDOTIALLSRYPREGTENCEtH)_-s $7,000 { TTT yl T 3 = . , _ a |3 l ": a j | _ L |B |bP | | _ a 3 ||/ a | _ a |3 | le | a | 1 !2 |l |I l |1 ¢10.000TIME(SEC)16:23JUN241991MON,HISTORICALW/LOADSHEDWINTER 1990.CASE 3B.43.5MW ANCH EXPORT,30MW KENAI IMPORT. BRADLEY LAKE 1 &2 AND COOPER 1 &2 ON-LINE.Q aTRIPDAVESCREEK-UNIVERSITY 115KV W/O FAULT.a WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.ox FILE:WIN3B2.CHN Yn 202-Ooarz3R a)z hl |SOLDOTNA_J1SKV VOLTAGE (PU)2H [1.3000 -=«0.30000|Q |SOLDOTNA _JISKV FREQUENCY (HZ)Pe)162.000 $7.000 |rea} T ||3 g o37.4: =os [2_|& o 3 i 4s o3Ql2-183 =3 |_l2 e =-: 3 =Te a ti re |||¢ DAVE SVS 986BERNICEBERNICESOLDOTNA 9968 9990 9989 SOLDOTIG HOPE 0.1 rity o.ol]>49 6.5 '3,2 -3.2f o¢flo.o 7)0.0 \4 0.9 -0.8 "S YO.0 0.0001 pavesocR |iT 1.6 0.0 ;.999 9906 tlo 0.0 -27.5 sore Svs >7-7 ek |.-9§.flo.5 -als |¢3S oS mS 0.0 ye--_-_3e882-4)o.of >6S Hg an 300.0 0.0 - iJ <3 a a 20.7 $,9 re O.1 QRT2 CR 1.116.792.6.2 9967 LIne ee a . 0.998 SKI HILL =22.8 23.21-19.0 27.2 a4 3.4 "T.02.2 , '1.022 LAWING 0.998 H -23. 27.7 'orTz cr YX"1.020 '9993 =23.1 4 NIN Oa) 'ye His TESORO |}'=|°a":'69 in -2 ' ;' t t r)L rT ' ''a 1 'COOP LK w/%1.023 vy ''9991 moO -22,4 '-----927 '"Hekwe'KASILOF '|' r=}ay anh t ''ye ONolenzl\-'(1)1 =r aT wu? '!elo elo . ;' '' '' ee ee ''BEAVR TP,0.961 ' 70 28.5 ' -'eye 'ole ' a ' a a0 t BEAVR CR ' ' ' ' 0.965 ' -0 ' ' ' ' ' ' ' ' a6 \ANCH PT ' ' a '°°'DIAM RDG Tie 0.958 '9965 iy3 -31.5 1win' e iM wad Lyrc)-_Hhotow3eg10.1 '' 2a 2 2.8 i a t f] ' FRITZ CR 'BRAD LK 9997 '500 Lecccccece ==pdoo 0.00.9 1.4 0.3 S 4 a meme ew neem ewe cee eee eee e eee --0§---9.0 (1)a wos L4H 0.0 5°0.30.95 0.000- .«<<31.5 0.0 t SPRING 1991.CASE 1.36.4MW ANCH EXPORT,26.6MW KENAI IMPORT(BERNICE LAKE 4 AND COOPER LAKE 1 &2 ON-LINE.MON,JUN 24 1991 10:14 KV:8569 ,€138 +6230 DAVE svS BERNICE BERNICE SOLDOTNA 6 nope4a0.0 9988 °*9989 SOLDOT1G 0.0 49 0.0 3 =16.9 17.0 _o¢floc ay?Scoll $*"76.4 S.2 "&Jo.d 0.000:"Daves?cR =!sin 1.0320.0 0.998 9986 'IA -33-0 0.0 -28.9 SOLD SVS - Ne98x5iedye 2 --0f-9.0 o alo elo |4.35,$a"0.0 ne 280.2 "at ' o.of |3.65 8 7S pn ogee0.0 |-=)=<° a f=) 48 ORTZ CR5,9 -« 3.5 RTZ C 1.2 Ciabet eet 9987 1.3me & 0,988 SKI HILL -22.9 23.31-19.030.4 a4 2.0 0.6H-O.2 ' =3b.0 1.Q87 6.9 9996yeoN3wrTLAWINGwl. SKI HILL A|N ""ffP012 2.021 723.9 8 Lh eran7+9 727.7 ortz cr "XY -s 2,027aoq 9 -23.1 a bre Cd ttl mo ale sotpoTua "J sig s|-TESORO Alt 0.987 ' 63 i ind 30.4 i ' ' 'alo COOP LK las 2.028'9991 ={v =22.5 'fe]- |xasrtor SI?2.012 3 '74 ths 28.1 SOLDOTNA Rn ;a a besry"nn ao NI"CS)cand'elo elo'1.@188 '¢ 'as 'KASILOF t Se ' BEAVR TP;0.973 70 28.5-God Linedmle 80 BEAVR CR f=) ANCH PT WI™75 Wo fast t=)de vee --DIAM RDG "IS 1.0179965-{7 =20.4 fat]hd .Hl herd e >at=10.0 p 23 SB 2.7 a FRITZ CR BRAD LK9997500 6.9 _os __ilo.o2.0 0.0 12.3 1.8 «. ©6 -12,7 12,8 $19,7anbt$1.4}f-2.2 0.4 ns 2.5 1 5°.9.3%1.020 1.029-.."--28.0 726.5 SPRING 1991.CASE 1B.36.4MW ANCH EXPORT,26.6MW KENAI IMPOR BRADLEY LAKE 1 AND COOPER LAKE 1 &2 ON-LINE. MON,JUN 24 1991 11:48 7 KV:669 ,£138 ,@230 SPRING 1991.CASE 1.36.4mMW ANCH EXPORT,26.6MW KENAI IMPORT BERNICE LAKE 4 AND COOPER LAKE 1 &2 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV #/O FAULT. WITH UNDERFREQUENCY LOAD SHEODING ENABLED.22016JUN241991MON,SOLDOTNA "L]5KV_VOLTAGE (PU)[1.3000 SOLDOTNA LISKV FREQUENCY (HZ)}62.000 1 |HISTORICALW/LOADSHED6.000012.0006.000010.00014.000TIME(SEC)4.0000SPRING 1991.CASE 1B.36.4mW ANCH EXPORT,26.6MW KENAI TIME(SEC)BRADLEY LAKE 1]AND COOPER LAKE 1 &2 ON-LINE.SsTRIPDAVESCREEK-UNIVERSITY 115KV W/O FAULT.gWITHUNDERFREQUENCYLOADSHEDDINGENABLED.-" FILE:SPRIB2.CHN a an - vr ™N 5 z= |SOLDOTNA_LISRV VOLTAGE (P90)|2 11.3000 0.30000| |SOLDOTNALISKY_FREQUENCY (HZ)162.000 --_57.000 | om T T I g 8 Zz 3| 3 |3 is \3Z3 az 3 3 3 L ry 3 < L d .we a 3 BRADLEYW/LOADSHED MF od 9991 °"31.3 .048 uS.7 Jo re oNainwl DAVE SVS 986BERNICEBERNICESOLDOTNA PE 8.6 9980 rr 9989 SOLDOTIG 0.0 HorasfiRe;3,2 3.28 os flo.o_yy***0.0 -3e--,n<r.2 -2.9 4 jo.0 0.000:Davech |FIM 1.024 0.0 1.002 9986 6 28.5 Z/0.0 -33.8 SOLD svs 9 ero.0.0 «"soln sloi=]-Le -ve3.92.6 4 §--535 ne $0.2 1!'0.0 -e-4P2%arts gen $88550.0 "a <° 19.3 $,2 o 0.6 QRTZ CR0.8i6.208 $-5 998 1.2R 5 1.004 SKI_HILL =23.2 23.59=30.4 -33.a4 0.2 2,642.3 010 LAWING 29.9 ortz cr "ZY 2.010 9993 -31. Sad Lat)ol wlio o|1oTESOROSle|! 69 bi ics Peetewweeweemeeweswows]teerer BEAVR TP!0.963 70 34.9-_ wn mln a0 BEAVR CR - ANCH PT %0.969 75 :-37.1 ww f=} -|*.OOOOOOewOeOOOTOFOOOeCOTOOSSSSESHSSTHESSSTESSEHHSERSETSSHOSETeewteneeeecane6 ANCH PT ed s|%0.963DIAMRDG. 965 THT 37.5 mw Pr)oy aleRey93i za e835 a FRITZ CR BRAD LK9997$00 arene |Onn EN |AOR)6.0 "1.3 0.3 =<vo 2 ee |SS eee|FE')po {-}4]o-0 °-3)o.963 0.000- .."«--37.6 0.0 io coop LK Sig 2.010 UJ eoSPRING 1991.CASE 2.48MW ANCH EXPORT,37.5MW KENAI IMPORT BERNICE LAKE 4 ON-LINE. MON,JUN 24 1991 10:12 KV:S69 ,£138 ,6230 DAVE SVS 966BERNICEBERNICE Hop9989990989SOLDOT1Grite 0.0 r 0.0 -}+--480.0 x4 -15.3 15.4 .s__flo.o 0.0 '3 -5.7 4.3 <Jo.o 0.000,"DavescR $FIM Lee 0.0 1.007 9986 Pee Ca) 28.4 0.0 34.9 tthe Svs win elo .0.0 =ole elooeLo-it eo -3.92 "a"-§0.0 ue 0.2 met ' 0.0 eli:"3s ge $850-0o.op 5°7 -A z P=9 £.8 QRTZ CR$.2 - "4.1 R 0.8 6.2 Rate 9987 1.25%o 6 0.998 SKI HILL 323.1 23.54=30.4 36.2 a4 1.6 -4.1Hee2 . 9996 <1.026 LAWING a -29.8SKIHILLS"ADoRTZcr"Y 1.026-9993 x 31.1 a AS SINslaolea2f) TESORO ic 0.998 69 i bre -36.2 t § ' coor tk cla 1.026,9991 SIP 31.1 a 'KASILOF =|":'74 Mest Ra 'a7 'oy bd ao bert'o1°o ola 'as 'KASILOF ' |nen --eeeeeecea ' BEAVR TP,0.982 70 34.7=ad bok)mln 80 BEAVR CR @ ANCH PT o/™1,02675VS5 Doel Enela ope a6 ANCH PT DIAM RDG "7%1,0279965-|o -34.5 wl &lod on"3 59.3)71!5a?eo a FRITZ CR BRAD LK9997t) 6.4 5 __Hoo 2.7 0.0 10.6 1.9 «-12,9 11,9 S$16.3rs}ra ry >anePsL.3[-2-2 0.5 <3.0 @) °-391,030 1.038re-34.1 =32.7 SPRING 1991.CASE 2B.48MW ANCH EXPORT,37.5MW KENAI IMPORT BRADLEY LAKE 1 ON-LINE. MON,JUN 24 1991 11:53 KV:£69 ,£138 ,6230 SPRING 1991.CASE 2.48MW ANCH EXPORT,37.5MW KENAI IMPORT SPRING 1991.CASE 2B.48MW ANCH EXPORT,37.5MW KENAI IMPORT BERNICE LAKE 4 ON-LINE.20 BRADLEY LAKE 1 ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT.=a}TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED.ox WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:SPR2A2.CHN n FILE:SPR2B2.CHN ostaeane)at 3 = 4H56SOLDOTWA}1SKV VOLTAGE (PU)|z SOLDOTNA _LISKV VOLTACE (PO){1.3006 --=©0.30000|fe [1.3000 ---©"0.30000|SOLDOTNALISKYFREQUENCY (#2)|o||SOLDOTNALESKVFREQUENCY (HZ)}162.000 ---s_57.000 |fa|[62.000 ---e 57.000 | 77)|j {|J |||34 I i |{||| |,a _Z | |*| |g \ = ,== |.43 = I g |"ls a Go|34La g =_/2 = \° a TioTk |oe io3 od C7- -le -- / a /TUL ./ ----,l L [>1}i | 20ve(a) ox7) 2Qnon4oO =A 5 = iz |§ a 23 g 3 3 Ggu s t z3& 3 3 3 DAVE SVS BERNICE BERNICE SOLDOTNA 9a6 NOP998899909989SOLDOTIG ® 0.0 254 O01 -fe--,473.0 oS 6,7 a.7h ¢[6.0 1)0.0 :ed i 4-4 2.7 "Ss 7.5 0.000:™pavesocR §SIM 1 4.6 J1.025 9986 the - 0.3 -35.6 SOLD svs 7 7 a=) .0.0 98 =ale * °+of vo -ay IT3.52 af 0.0 avo $0.2 o.o 2 reed "3 =e”200.0 0.0 "|"”im 4 °o .a a 17.2 4,2 Pry 1.9 QRTZ CR 0.515.6°%¢.8 998 1.05%<2 a 1.019 SKI HILL =25,3 25,7h=32.9 36.3 a4 3.4 -5.76.2 - 9996 °i 1036 LAWING SKI HILL SIS '-30.7 98 at 'QRTZ CR Y 2.038a'9993 32.0 win t and Dall oI =1 ed Aids aw t id oa °Tesoro Ji¢1.018 ' 69 TI? 36.4 ' T t '6 1 I ;1 i i Colo \'coop LK ols 1.038 '1.0500 '9991 ifs 32, 1 ao 0 }- '"e( RASTLOF SOLDOTNA 'RAfl_' 'a °' '='ee je\r o1°o oo 1 i] '(] '' ne a 1 ' -6BEAVRte}0.998 '-35.7=a Hwie' i ' ' a0 ' BEAVR CR ' ' -t +o tANCHPTTI.5 1.011 ' 7 o 37.7 ' ' ' t ' s ' i] $ ' 4 ' ' wn \DIAM RDG ol 1.006 ;9965 144 38.1 '"pe é &cad 'i aE ai-t or s a 2.1 'za 4 ' a 1 a ! FRITZ CR ;BRAD LK9997'500 Lo------8g._flo.e 0.0 -1 0.2 Se a |Sie -=-o-2__(J)-=$121i 0.0 5°0.20)006 0.000 -.."a-38.1 0.0 SPRING 1991.CASE 3.49.9MW ANCH EXPORT,39.3MW KENAI IMPORT BERNICE LAKE 3 AND SOLDOTNA ON-LINE. MON,JUN 24 1991 10:22 KV:69 ,£138 ,6230 a", DAVE SVS 966BERNICEBERNICESOLDOTNA 9988 9990 9989 SOLDOT1G HOPE 228 9994 9.9 -}e--a90.0 3 -13.3 3.4 ¢flo.)rN)' *%407 32g <<«ow 0.0001 % pavesocR |ait 1,0280.0 2.010 9906 pans =29.3 =/0.0 36.sop svs =P)Ola :0,0 «as leo -be -u ” 3.32.6 $755 ne $0.2 "!'0.0 }e--ie:eZ an 350.0 0.0 -a z 8 8.0 4.2 .o =4.4 QRTZ CR 0.515.607 gon 998?pf ameteo 8 1,003 SKI HILL =25.2 25.78 -32.8 37.2 84 2.4 4,604.8 9996 °ole LAWING SKI HILL «|S -30.8 96 =QRTZ CR a 1,027ole9993 32. oy NIN ol TE ba hid a0 oesorolS1.00269TI?-37.3 ' a ' i)coop LK 3;2.027 'i 9991 FIP =32) 023 i”' 69.0 'min Parry 'Aallen«4 \1 'ro)er 9'slo ola t ' a ' iey 4 BEAVR TP,0.985 -35.9 wie wl 80 BEAVR CR . ANCH PT 75 ny A t=) DIAM RDG Gl™1.024996511036.3 i fe2>rity=o22-1 a FRITZ CR BRAD LK999700 ris _os _tlo.o i.8 0.0 7.6 1.6 «6.7 8.8 Ss 10.4 1)uo ™2 : nok du -1.8 70.9 ns 1.2 15ve::Wh oes 3.032zo"36.2 =35.0 a4 SPRING 1991.CASE 3B.49.9MW ANCH EXPORT,39.3MW KENAI IMPOR i BRADLEY LAKE 1 ON-LINE. MON,JUN 24 1991 12:00 KV:569 ,£138 ,€230 SPRING 1991.CASE 3.49.9MW ANCH EXPORT,39.3MW KENAI IMPORT BERNICE LAKE 3 AND SOLDOTNA ON-LINE. TRIP DAVES CREEK-UNIVERSITY 115KV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDDING ENABLED. FILE:SPR3IA2.CHN SOLPOTNALISKVVOLTAGE (P0)}1.3000 0.30000 | I SOLDOTNAL15KVFREQUENCY {Hz)|162.000 ---#$7.000 | TTY rT Ty 1 3 +}a:|3 |= I 3 |Ts L aE: ?-|« Lo |8 |s L |3 |a 7 |a oe| Lo |3 |e |3 _[3 |- le |3 =-j]¢\ro) =<{ST |!by 16:18JUN241991MON,HISTORICALW/LOADSHEDTIME(SEC)SPRING 1991.CASE 3B.49.9MW ANCH EXPORT,3 BRADLEY LAKE I ON-LINE. 9.3MW KENAI IMPOR TRIP DAVES CREEK-UNIVERSITY LISKV W/O FAULT. WITH UNDERFREQUENCY LOAD SHEDOING ENABLED. FILE:SPR3IB2.CHN SOLDOTNA JISKV VOLTAGE (PO) SOLDOTNA_1}SKY FREQUENCY (AZ) ---<€0.30000|--_-"1 t 1 1 16.0008.00064.000038.00014.000 AUG-14-91 WED S9:e6 PTI . P.e1 Jw POWER TECHNOLOGIES,INC. FACSIMILE TRANSMISSION One Sierragate Plaza {Suite 340B Total Pages:_(Roseville,CA 95678 Fax #:(916)783-2086 Tel #;(916)783-3566 rox Qcove.Boden vaneFROM:sp eatDATE:'e-lA-mae AS GG Belig.,an.Baden "6 2EP,Foe 6&2,hinaeAAcpeegpoworeldloneay?LavetrataSp-braney gas Noms retin,Ain eticySaka.Poor,2rre Ln EP Dalold de Lhe-atlhyw os ee -VsrKuaes [lore porrepfaceBGLaoowyasoLegricastg-oprretef Upolves noe opto"SS2°Protest optcatey ob,Uheann <etek R=95%mee °000 08-14-91 O8SOSaM'PODLT HIS” US--14-91 weD 15:3"PTI PrP.o1 1w 95% POWER TECHNOLOGIES,INC.oarFACSIMILE TRANSMISSION One Sierragate Plaza -Suite 340B Total Pages:10 Roseville,CA 95678 Fax #:(916)783-2086 Tel #:(916)783-3566 TO :Dave Burlingame FROM:John Doudna DATE:August 14,1991 SUBJECT:Results For Today's Bradley Tests Here is the last case I have time to min today.This is ran on the same hase case as used in the previous cases.This is for the trip of both Bradley units at 90 MW withouth the application of a fault.The frequency in the Anchorage area drops to a little below 59.4 Hz,However,this may be optimistic for this generation loss since it appears that Beluga 3 and AMLP 7 bumped into the exhaust gas temperature limit.Since we have concluded that our model does not give valid results when CTs hit exhaust gas temperature limits,I would be a little hesitent to say that Bradley at 90 MW could be tripped withont going into load shedding for this generation condition.I think at least one more CT in the Anchorage area at least would be needed to allow Bradley to be trippedatthislevelwithoutgoingintoloadshedding. ann ae ea me ae mene I will see you tomorrow. =SFREQENCIWED,AUG14199215:07aUG-14--91 WED 15:5 PT.( INITIAL CONDITIONS FOR 14AUG91 q.1700 ERS.BRAD 1 &2 @ 45MNSOLDOTNA,BLPP 3 &4 ,MLP 6,&8,BELUGA 3,6,5 &8 ON,TRIP OF BOTH BRADLEY UNITS @ SOMW @ fT =10.0 SEC.NO PAIIL.T.BELUGA 8 GOVERNOR BIOCKED. FILZ:BRAD TRP.CHN GOLD RILL 138KV_(H3) 60.100 errr °"35100 BRADLEY 115KV_(82)60.100 -=-a $9.100 AMLP_230KV_(82) 60.100 oo 59.100 |1 1 |||I || --- -i - é {|||||||23.0¢021.€0017.00013.0009.00005.0000RwAsAX naa =-;15.00019.00023.000TIME(SEC)41.00067.0000 weP.os15:35"periWEDUG -1i4-91 (8 dINW OL "IWY)SRIONV (9aS) FRIL ShiS> 66T FISov 'aaM noo'tz oooet s00"st 900'T oo0e't 000°SZ 000°T2 o00°Lt 000°CTt 6000°S e000" 2lelelele | || ||| & sjisis$8|8 eo. eoAotet4 mee i}(]()1)i)_ - Dwadaun erieoir| wre .';J - "Sg onetn} . 3i" n(n eb renee aes ean Faeee % y oaoa trod s=z = vod - Om l-l | Cd e Pryeel @ ad|=)&is ' APe aee eee co37 Tg - veneeany _ Owea 5 ae cane) otdae "s, Pane 8 a2 Cea sdaee 2 % steem fpee pce %Eom *a Bewmwww eesecncers Mee vcrvessovrscceseee® werent a _! Beep5 ' *s, > | a:le ee ee penne 838 a - yen £4Ae0BETaetter | BAARAShE = _| eoeeo fo] °o [o} oe6a a BAAR wefANe142901ND-Gedownoot-95% RUG-14--91 WED 15:57 PTI . (P.o¢ INITIAL CONDITIONS FOR 14AUGS91 @ 1700 ERS.BRAD 1 &2 @ 45MW SOLDOTNA,BLPP 3 &4,MIP 6,7 &8,BELUGA 3,6,7 &8 ON.ofTRIPOFBOTHBRADLEYUNITS@S0MW@T=10.0 SEC.NO FAULT.-OBELUGA8GOVERNORBLOCKED.24FILE:BRAD- TRP .CHN fy «i2 Oiet«20xaBO POWER (Mit)a 100.00 --t 100.0 Ss s|I |s & a a _| re} 2 fe : -13 __ 28 a:__|s=--_|2%=>- _18 |{|l |l !||8 =95%nan \UG-14--91 WED 15:5°°PTI P.o7 A)INITIAL CONDITIONS FOR 14A0G91_@ 1700 HRS.BRAD 1 &2 @ 45MWSOLDOTNA,BLPP 3 &4,MLP 6,7 &8,BELUGA 3,6,7 &8 ON.=0cTRIPOFBOTHBRADLEYUNITS@90MW@T=10.0 SEC.NO PAULT.oe ttsuoBELUGA8GOVERNORBLOCKED.8 FILE:BRAD-TRP.CHN udta) "Aoe LJ te| 8& 78.000 en - «0.0 E 100.00 ---s 0.0 |1 ||8 2 -J -3 2 8 "3 3 "715 38=-_)iga | 3 i -"14 oe -_|8 - }___° 3 -|zi 1 i !R 3|+ 1 l 8 ||||||Ly 1 | =95%7 AUG-14-91 MED 15:5°°PTI {Plas SOLDOTNA,BLPP 3 &€4,MLP 6,7 &8,BELUGA3,6,7 &8 ON.TRIP OF BOTH BRADLEY UNITS @ S0MW @ T =10.0 SEC.NO FAULT. BELUGA 8 GOVERNOR BLOCKED. PILZ:BRAD-TRP .CHN it INITIAL CONDITIONS FOR 14AUG91 @ 1700 HRS.BRAD 1 &2 @ 45MW WED,AUG14199115:19BERNICELAKE#3MECHANICALPOWER(pW)28.000 -:rn=6.9 -__ELECTRICAL POWER_(W)7 40.000 4 -10.600 l |||TTT yl 8 I a.fo : )"TR I f 3 =- 1 i 3 -t "4 ! f 2 =1 7 !S138 )"8&”3 Ge-_<r "713 eo -<- y | .ww \8LW{_|2 ]{ 1 $ =3 | Ss ||L j l ||u S re QhY tUG-14-91 WED 15:5 PT.(-.2@28 aT)INITIAL CONDITIONS FOR 14A0G91 @ 1700 HRS.BRAD 1 &2 @ 45MWSOLDOTNA,BLPP 3 &4,MLP 6,76,BELUGA 3,6,76 8 ON.ar 7)TRIP OF BOTH BRADLEY UNITS @ SOMW @ fT =10.0 SEC.NO FAULT. BELUGA 8 GOVERNOR BLOCKED.al aFILE:BRAD-TRP.CHN €a0aQyas ) a |BELUGA$9_PM (PU2.0000 =--=St +570 8 aBELUGA#7 PM (PU)at1.0000 Poeccmescon=°0.0 wo) BPLOGA #6 PM (PD)Z 24.0000 --------<0.0 reBELUGA#3 PM (PU)-_1.5090 |o5 0.0 a TTT rn T 8 'n 1 8 "e = t e|"1at ' }2 t S =L "Ia | ' ,\. q (2 -|<1 -7 |' §8 !-- ,|- sucodi.a 4!i ]= t s & ¢nn\'” \1 a ss,:_|8}t - \a rf ' 's1 |{8 } |Pet g !2°|| | ,3 :l l a cee [Gee l = =94% °UG-14--931 WED 1529°PTS to. (P.o6 2 @ 45M &INITIAL CONDITIONS FOR 24A0G91_e 1700 HRS.BRAD 1 ¢&SOLDOTNA,BLPP 3 &4,MLP 6,7 &8,BELUGA 3,6,7 &8 ON,ballSaTRIPOFROTRRRADIRYUNITS@oases@f=10.0 SEC.NO FAULT.ce tte BELUGA 8 GOVERNOR BLOCKED.0PILE:BRAD-TRP ,CHN Hde anm ed Ldet 8«< MECHANICAL POWER (MW)a 75.000 -: V------«6.0 100.00 tl eee)0.0 4 ont tJ4!{|1 (|{i |8 s Ft ]:3 |a i _!2I"ls | a,3 { I ° -3 ;)" j |=28 "0|«4 ;eF:3 i)Of aebe \-"- 'XN o 4 r cs 2 ed 1 en 1 ] I 2 _{_id{ |8|i]a |_}||||[:: 94%nan an ase. WWG-8£6--81 MED 35:5 PT,; (P.aso 4)INITIAL CONDITIONS FOR 14A0G91 @ 2700 HRS.BRAD 1 &2 @ 45MWSOLDOTNA,BLPP 3 &4,MIP 6,7 &&,BELUGA 3,6,7 &8 ON.wl TRIP OF BOTH BRADLEY UNITS @ SOMW @ T =10.0 SEC.NO FAULT.BELUGA 8 GOVERNOR BLOCKED. PILE:BRAD-TRP.CHN WED,AUG14199115:29BERNICELAKE#4MECHANICALPOWER(00)25.000 -Ww"es 0.0 ELECTRICAL,POWER (MW)40.060 -_-_--t -10.00 25.00023.00021.000T l |!| -| b4 eo a a 8 2 28a2 °& =_ls +,a° - _ -_\_3 --a 7.0000}weeeeote|9.0000=$.000)ARN WG-14-91 WED 13:5 Pre:. t Poe TNTTTAT.CONDITIONS FOR 14AUG91 @ 1700 HRS.BRAD 1 &2 @ 65MWSOLDOTNA,BLPP 3 &4,NLP 6,7 &8,BELUGA 3,6,7 &8 OM.seaTRIPOFBOTHBRADLEYUNITS@SOM@T=10.0 SFC.RO PANT.3BELUGA8GOVERNORBLOCKED, FILE:BRAD-TRE.CIN Sspa20#4«8etCo)oun< MECHANICAL,POWER (MW)_B $0.000 -,nom -0.9 -ce oeLECTRICALPOWER (IW)10.000 ----a__ 10.00 {}|i |||4!1 s !8 \s y !3 | : J 4 8Lo,4: t !: -\an (3/5Aeo 84 'a SY /=\ss 7 °” ¢ = . sA _|g .ey,CL a ----"N s =|_|8a 7 \ |4 j g | )8 l l l l l on a are & aGAK aan CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska June 29,1992 TO:Dave Eberle,Alaska Energy Authority FROM:David W.Burlingame,Manager,Power Control SUBJECT:Bradley Lake Governor Stability In completing the underfrequency loadshedding study for the Railbelt,PTI has-encountered a severe problem with governor stability following islanding conditions.The underfrequency loadshedding study has indicated Bradley Lake is unable to stabilize the frequency as was shown in earlier studies. On the June 3,1992 voltage collapse,the Kenai islanded on two separate occasions,the first time there was approximately 90 MW onBradleyLakewhenthevoltagecollapsed.and the Kenai islanded withonlyBradleyon-line.Frequency varied from 62.67 to 58.5 Hz.The Kenai suffered severe over and underfrequency swings until one unit was placed in deflector. The second time islanding ocurred,one unit was still in deflector, with Bradley at approximately 80 MW.Frequency ranged from 62.7 to 58.2 Hz,but oscillated for only a very short time. We have enclosed a frequency plot of the events described alongwiththefrequencyplotsperformedearlierfortheTCSinsettingtheBradleyLakeoperatinglimits. The earlier PTI plots show a smooth frequency transition followingislandingwhichisthedesiredresponse. Please have SWEC investigate and report to the the TCS as to what corrective action is required to achieve governor stabilityfollowingislanding. ce:Tcs Relaying/Reliability members S.Sieczkowski -AEA CASE E.WINTER OFF-PEAK LOAD,25MW EXPORT @ DAVES CREEK. KENAI GEN:65MW @ BRADLEY §&16HW @ COOPER.4C/3P FAULT @ BRADLEY,TRIP SOLOOTNA LINE NO REMEDIAL ACTIONS. FILE:25B865E01.CHN|HEALY )RELATIVEROTORANGLE100.00 as 100.0||MLEP_7 RELATIVE ROTOR ANGLE100.00 ee 100.0}|COOPER}RELATIVE ROTOR ANGLEJ100.00 ae 100.0||BERNICE9RELATIVEROTOR ANGLE100.00 ete tatodad.=100.0 | f RADL OTOR ANGLE 100.00 ---4 -100.0 | |BRADLEY2RELATIVEROTOR ANGLE{100.00 -_--1 -100.0 | rT TT 3 5\a (]|'_ i] ' '3 =\_j2 .' =- 3 2 3-_¢In ' ' ' t =4 ' i ';3i]a -st '"|r iN =_ a3 Q ="la =-_ l I |.e 4.$0003.50001.3000o [¢p | _g&eG 7 neGO% AM Ooe id rc) 9 a! ial € CASE E.WINTER OFF-PEAK LOAD.25MW EXPORT @ DAVES CREEK. KENAL GEN:6564 @ BRADLEY &I6MW @ COOPER.24c/3P FAULT @ BRADLEY,TRIP SOLDOTNA LINE v NO REMEDIAL ACTIONS.5 FILE:2586560).CHN & n we re ot Le]8 U UgNC 4]e 77.006 TST ST W000|i|AMLP 290 KV BUS FREQUENCY (HEL 63.000 tL )$6.000)og SOLDOTNA 115 KV BUS FREQUENCY (HE)e [63.000 --_-*$9.000| PRAOLEY13 KY BUS FREQUENCY IKE)j {63.000 $4.000 | |{|1 |J |3 2 "3 a =oe "iii!2"° ="Ta 3 =44 _438 ) 3t-J = 14 ji 3 a =os 3 =os Lt 4 py \yof 4 3 FREOASLIENCY Pres tas Ghats,Oe ae Te DUN UU TOLUoCeawe T ee ee Me RO LO (A ie eR TRCUGSCWU WG hneae CU IUD UT lstteae-,Ro &'a '",=a "a ,°,*"a w 'lt a .P/3f9E O4gd te BF RY OE Bhagat votbe BU |one Sta ng:PO Rn Se Re LOAod bo Lh .ree ane es ooh ean GNM Gsm.Map On eneesee UF a Se meNER BED Sect Gre Gun ener Ce a oe ReeC CMOee Se Ro We CC ee |ae Tr AS es,Beets, 3 N)'t)° 2215.25 (eoSs) _Aa (Vetiow a).Ih bea SEa)'i ”C1 SSKV b6-ce 'J f by ha fPrter imal t ley ewe fade ?An oy 41h”Ca ;thy mt"7 "hh yt 4,va ia,spent vracvorwehetone tay "L sy Saw (dos)fh hy,ve ee alae ft ' we ets a a ub tS 'frail E+le.2S!(10653)'7)a 1 Ban (6415 re 'kil,I ot.se v3 Tone,)om f 64.6 Kv {cM Ma ha Oman 3lesanaMfOeene)/ os (00)(aU $8.30 43 14.0 lex) $4.8 uv Wet f w ;(I {it °&:1a4mn (4525) Vs14.oekeTae'(st36s) cane . |sPleye |soap]EL tet /see ot sarsacasne nen efe Ce oe ee Ce {-a gee nS eer enn Qes 4 Oe ete |Coe oe Chereoeoe |.CP a wwonef ane +uum es Que or we leopaie ag ae lo.Po orDa ee «f 1 Greer q e ot 2 ran ee "a mf oe i)te «Hii teri,Oh et a igh,{aan a ent a roe Se Ol BU Oe!Begs SE PRT 'ware Be FE NET BA Gee eT PI Ae BHa BR OEE Ea we Pee Oe Ge BO GP ee BO RE pte feb a re Bee b Wyle ft fre esd eae in"HH 4 ans Gay igen aeaee &wee weed onsen Re wom f tek ta od lh de et ee ee ee Le so Oepem wwfoe Cr oe Oo +727(13%) fect.Hy 1 my By oF ROME rie tl eet ieee A Mee OO a Roa an nay MT oe om Be | (+B.S 'Utezs) f=6o.8 thy peemyenfomeeeenseucen-enefareeuresnenemerWrit,0 eon, CO Se eR OU PO ee ane ey "4 A ie Ae SG LE a a Fe We Ok aU A aC OS Te BALnn aL RN SA eaeek OTeDsMae PDaaTD eas BaCeg/92 G8 t PLPP bu elder MMe CR th a elol Se ne ee ee Pe Poe ee Me Con Sek cone,cent tneeeon Oe ae er ed ee en ee Peereners eT een ernr fang*67,66€*(0.28'(13073) Jenna¥$8.20 ts 1.45 (10875) fax 63.62% é=1.4"(19845) net rebags...|paleatl |Fobiaiaiaheniateed ud be t€*12.83 (14603) $254.94 J f200 ee eee Pe ecaneOe Ue Ue TRO SE IA He UOT,OS Rk CO ae ee eC ae Dn Aa 1EO0 coi,0 id SENT BY:i T=1-92 5 14°32 ¢AK ENERGY AUTHORITY 907 562 O0275#2 JUL=1-892 WED 14212 PTI"WESTERN OFFICE P.a@2 POWER TECHNOLOGIES,INC, FACSIMILE TRANSMISSION One Sierragate Plaza Fax #:(916)783-2088 Suite 340B Total Pages:10 Roseville,CA 95878 Tel @:(918)783-3568 TO:John Yale COPIES TO: .Dave Eberle -AEA . FROM:John Doucna Rodolfo Koessier -PT! DATE:July 1,1992 om woeSUBJECT:Bradley Frequency Regulation We have reosived and reviewed a DSM recording (attached)provided by Dave Burlingame fora June 3 event where the Kenal system became isolated with only the Bradiey Lake units on-line and with both unit operating In the needle control mode.Thig recording shows wide frequency deviations which lasted several minutes.The frequency oscillationa were finally damped when one of the Gradley units was put Into the deflector control mode. in the past several days,we have observed some significant oscillations in our studies while evaluating underfrequency load shedding requirements for the Kenal system.Our Initial thought was that the oscillations were due to the AGC action which we were trying to repiloate In our model,However,after recetving the OSM recording,we began to wonder ff the cacillation problem was solely due to AGC action,or whether the Bradiey governor PID controller gains could slso be contibuting to the problem.. To Investigate this matter further,we ran @ series of simulations to evaluate Bradley's frequency regulation characteristics when operating on af Isolated Kenai system.For these simulations,we eliminated all AGC control and undertrequency load shedding from our model In order to observe Gradiey's 'natural characteristics.For our simulations,we used &normal Kenai winter load Condition with the Kena!importing 8 MW at Daves Creek.We then isolated the Kena!across the University-Daves Creek fine and observed the Kenai trequency at Sowotmia for a period of 180 seconde (3 minutes). R=94%9075618584 O7-OT=3E O2TIZPM "FUOS #T a ee 41-32 wED SENT BY:3 7 1°92 +14:33 +AK ENERGY AUTHORITY $07 $62 002738 3 243438 PTIOCWESTERN OCrPICE PrP.os Power Technologies,inc,;Page 2 Our series of simulations consisted of four Bradley Lake operating situations and govemor contro!scenarios.These are summarized as follows: SPEED REG TEST #1 °One Bradley unit in needie conuyol using on-line PID gains SPEED REG TEST #2 'Two Bradiey unita In needle control using on-line PID gains SPEED REG TEST #3 .Two Sradiay units using on-line PID gains &Initially in needle control. One Bradley unit toggled to deflector control at 59.5 He. SPEED REG TEST #4 °Two Bradley units in needle contro!using off-line PID galns The results are shown In the attached PSS/E dynamic simulation plots.These plots show the frequency at Soldotna.This frequency is Indicative of the frequency on the entire Isolated Kanal system.A drief discussion of each case follows. SPEEDO REQ TEST #1 Upon isolation of the Kenal,the frequency dips to near §9 Hz,and then recovers to about 60.7 Hz.The Kena!frequency oscillates for the entire 160 second simulation period with a period of oscillation of about 24 seconds.The frequency dsoillation is sinus,Indicating there are no non-linear contro!actions present.There is a small amount of damping on each subsequent awing,and the frequency deviation dies down to about 0.68 Hz peak-to-peak by the end of the simulation. SPEED REG TEST #2 Upon Isolation of the Kenal,the frequency dips to near 58.8 Hz,and then recovers to about 61.5 Hz.The Kena!frequency oscillates wildly for the entire 180 second simulation period with @ period of oscillation of about 28 seconds.The frequency oscillation is not sinus, particularly on the posRive-gcing frequency excursions.This indicates there are non-linear contro!actions present.This 'the resuit of deflector action.There is no damping of the cscitations.Thus,the frequency ceviations do not diminish,but they do not grow elther due to the non-linear control Imposed by the deflector.This oscillation scenario approaches that observed In the DSM recording. R-94%:9075618584 07-01-92 02:42PM PO03 #35 SENT BY:;7-1°92 5 14:34 +AK ENERGY AUTHORITY 907 582 O027:%4 _FuUbL--1-892 MED 14281344 FPTI-WESTERN OFFICE PrP.O44 Power Technologies,Inc.Pages SPEED REG TEST #3 Upon isolation of the Kenai,the frequency dips to near 68.7 Hz,and then recovers to about 61.5 Hz.However,at the paint where the Kenal frequency first reaches 59.5 Hz,Bradley Lake #1 was toggled Into the deflector control mode.As can be observed,this action causes the Kenal oscillations to cease after the first positive-golng frequency excursion.This Is comparable to what was observed from the OSM recording after one un!t was toggted Into the deflector control mode. SPEED REG TEST #4 This case Is the same as Speed Reg Test #2,but the Braciey governors are using the off line PID gain settings rather that the on-line values.Upon Isolation of the Kenai,the frequency dips to near 58.6 Hz before tuming around and gradually going toward 60 Hz. As the Kenai frequency recovers,there are small frequency oscillations with a swing period of about 24 seconds.However,these oscillations ara small and fairly well damped. From this series of simulations,we can conclude that the on-line PID gain settings used In the Bradley Lake governors provide unstable control on an iselated Kenal system with no other generation (1.e.,fast responding generation fike the Bernice Lake or Soldotna CTs) on-line.This contre!instabifity becomes worse when beth Bradley Lake units are on-line. These govemor PID gain settings are probably the prima caves for the large frequency deviations which have been ebsarved under Isolated operation.However,since the oscillation magnitudes observed In our simulations are less than those observed from theOSMrecording,we fael that the AGC is also contributing to the frequency deviation problem. Even If the governor controls were stable,the AGC could 'upset the apple cart'If It le trying to force Bradley to respond beyond Its physical capability, Using off-line PID gains in the Bradley governors (theses are the galns presently used when the generator breaker is cpen)substantially improves frequency performance when the Kenal system Is isolated and operating with only Bradley Lake.if these gains were used all of the time,the systam would be inherently stable (from a control perepective).However,Bradisy's response capability would be diminished during Interconnected system operation.Further, during isolated system operation,Bradley's response would likewise be slower and this could aggravate the control interface problem with the present AGC system.The AGC system is already trying to move Bradley faster than It can physically move.If Bradley's governor controls are made jese responsive by using the off-line PID gains,the differance between what the AGG wants and Bradley can deliver wil become even larger. Re9G4X%:907561858T ="-OT-O1-G2 VZTT2PM OF OOS 855 SENT BY:+T=1°82 3 14:34 +AK ENERGY AUTHORITY 907 582 002758 § JUL-1-892 WED 1427134 PTI"WESTERN OFFICE P.e8 Power Technologies,Inc.Page 4 Perhaps the optimum and best control strategy to use on Bradley during isolated condBions is to toggle one unit into the deflector control made.Deflector control provides for more stable frequency response since it decouples the electric system response from Braciey's hydraulic system constraints.Further,it allows the unit to be as responsive as the AGC system wants It to be.Thus,operation with one unit in the deflector contro!mode during Isolated Kanal operating situations will avoid both govemor control and AGC instability problems which are presently experienced. The deflector contro!mode was first recommended in the surge tank study.In reviewing the report on this study,it was suggested that the deflector control mode could be triggered by: .SCADA upon detection of Kenal islanding °dispatchers or unlit operators through a switch*-anunderfrequency relay To our knowledge,only one of these options for putting Bradley In the deflector contra!mode - has been implemented (1.¢.,the dispatcher or unit operator convolled switch).This may be adequate for situations where it /s planned to isolate the Kena).However,based on the one documented operating event,this appears to be ineffective sinoa it tnok several minutes for the dispatchers to put one Bradley unit In the deflector contro!mode.To improve frequancy performance during unexpected Kenai isolated operating situations,we feel Ht would be prudent to Implement deflector control toggling on one Bradley unit ueing one of the automatic schemes previously suggested. Toggling to the deflector control mode based on frequency deviation at Bradley.may implement deflector control when it Is not needed.However,this can be done locally at Bradiey and does not rely on SCADA or communication tinks to the plant.This controlStrategymayresultinwastingsomewateratBradley,but #assures system frequency stability under all situations.In the long term it s an accaptable option,but In the Interim operating poriod (i.e.,before the GVC are cparational)it could create some problems.In the Interim operating period,if Bradley were switched Into deflector contro!under an interoonnected situation,Bradley could become to responsive to Rallbslt frequency decays and could potentially force the Kenal system to go out-of-step. imptementation of deflector mode toggling based on SCADA detection of an Isolated Kena!system would only automatically Implement deflector contro!if the Kenai syatam became isolated.However,this requires the SCADA system and communication links to Bradiey to R-94%:9075618584 7 OT-OUT=S2 02:T2FK POOs #35 SENT BY:>T=1992 +14:35 +AK ENERGY AUTHORITY 907 562 0027:8 6 JSUL-21-92 WED 141515 PTI-WNESTERN OFFICE Pp.66 Power Technologies,Inc.Page § be operational at all times in order to assure proper action when It is needed. A hybrid control scheme could also be developed.This schame would have both automatic SCADA and frequency control over toggling to the defiector contro!mode at Bradley.Elther or both could implement deflector control if the Kena]became Isolated or the frequency - deviated beyond some bounds.If the frequency deviated and Bradiey was toggled to deflector control,but the Kenai had not become isolated,then SCADA caulki detect this and automatically toggle the unit back to needle control. Yet another option would be for SCADA to detect the Isolation of the Kenal and Issua an alarm to the dispatchers.The dispatchers could then toggle one Bradley unitta the dafiactor contre!mode.However,this again relies on the availability of SCADA and the communications links to Bradley.Further,it assumes that the dispatchers will not become 80 preoceupled with other problems that they fall to take action promptly. Please advise if you have any questions on this matter or #you would like to discuss #t further,' fA. Reg94x 9075616584 _'-"-"O7-UT=92 oF42PM POO 255 KV60ayeseBi19s.0sGEH#LOOdMd2VZN.26-30-10mapawen7|oo.yaaPare worse &&a few CNet© A,WEEE FUE.bad”EET POP CENere ery TI REE .S7 NET 'Rrergec"SErecrErTes25:31 ILPP Sus freauancy -Hz ; |64.0° 2.65 \ ---oe ms ene go O°Ganee oD-Qwe:.Umer eee t 7°27 (vs) faurssy| chi teats ili ,atore)ee /-_I i{240.0 4.©5820 245°(rests) L e Lage 83ALty=00.6"(uns) -t-4 4 eheven f.G A ff 460 0 206.4 Tt an to aati f;SUR (2a0g teat t 2004.9 -an2e348LNSSoudWYSELT2€-aum26--TNALIETSRIVOCEDXKriaSteetGe:vb$ZBL<b¢h/tvamagua.SROPEBLPG,08eALIMOHLAYADYSNSYY:eao°dL#51200295L06 SENT BY:+T=1992 +14:38 +AK ENERGY AUTHORITY $07 582 0027:3 8 JUL-=1-92 WED 123212 PTI-HESTERN OFFICE -.eT |WORMAL WINTER LOAD.COOPER @ 16MM.3MW XZNAI IMPORT.Nn ONE BRADLEY UNIT @ SSMW OCUTPOT.XKENAI ISLANDED FROM SYSTEM WITH 3NW IMPORT.|]BRADLEY IN NEEDLE CONTROL MODE WITH ON-LINE GAINS.FILE:SPEDREG1.CEN WED,JUL61199208:46SPEEDREGTEST#1BOLOOTVA FRLOORNCY (EE).-_--_--s43.000 38.000 im |j {i ||t : .ts =_|s 4 ._|85 |90.000TIME(SEC)|}72.000I54.000Tr36.000\:R=94K "2"gOqBBTEBEL- UY=UT=S2 02:42PM "PNA ete SENT BY:+T=1-82 +14:36 +AK ENERGY AUTHORITY 907 562 0027;8 9 JUL--t-92 Wid 1 8123 PTIK"WSTRN OFFIC:P. |KENAIT ISLANDED FROM GYSTEN WITH 3MW IMPORT. BRADLEY IN NEEDLE CONTROL MODE WITH ON-LINE GAINS. PILE!SPEDREGZ .CHN NORMAL WINTER LOAD.COOPER @ OFT.-|TWO BRADLEY UNITS @ 75KMW TOTAL OUTPUT.3MW KENAI IMPORT.WED,JUL01199208:23SPEEDREGTEST#263.000 T T T g $ =g 3 g =|34 = 3 "ie --_-ee"Tg-oe: a mls -: "18 L..>|oo 3i:| |od l |peer l ¢ R=94%9075618584 "97-01-92 OFTeZPM FOOT #35 SENT BY:$T=1-82 ;14:38 +AK ENERGY AUTHORITY $07 582 0027+810 JUL=1-92 WED 18512135 PTI-WESTERN OFFICE P.as KENAI ISLANDED FROM SYSTEM WITH SMW INPORT.OnsetGAINS.BRADLEY @1 PUT IN DEFLECTOR CONTROL @ 59.5 BZ. FILE:SPEOREGS .CEN ORMAL WINTER LOAD,COOPER @ OFF.=aNO BRADIZY UNITS @ SMW TOTAL CUTPOT.MW KENAT rronr,WED,JUL01199208:26SPEEDREGTEST#363.000 ACLROTED TEES EESS LOR)----Ss {{||{||8 : 3 La -_j]2a =_i§ " ,3 -"3 ; /jaazf +) Z i = -_|%a -_ za]"8 |||ee L_fe R=94%_ oe SO7SETESSS "=97-OT=SFUF:42EM FOTT 235 GER 110d WdeZPi20 2610-20...SBI9SLO6 «4 er °{1 |[{] 3 _ | 3 £1 3 = aL j si.g 3 3|_ g ne gL _ g = 2 -- ae _ g 5 |||||||||{ |cco'ss 000'ts wren HY -XONISONLY WRISSTSSU{ 6ai :Qe SHe ”f\-Red'pHemUaadS 'TILL ="SNIVO ANII-dsO HIIN ZOCON TOWINOD TIQUIN NI XZ1CVeG the se "IMOQNE WHE HEIN NILSXS WOUL CSCNWISI IVMIN|ad Mg *SYOGKI INNZN UNE "LO42NO IWLOL ANSEL 9 SLIRNN AMIAVUE OM |*220 §UBACOD 'AYOT VALNIM IVNUON| Std ZBSDIi act O NMRLSEMaeITid B2tFt2®™aem SCOr?t HANS LL8i L200 285 LO6 eALIMGHLNY ADYSNS WY $LEsvt $7Rat -! CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska July 8,1992 TO:Railbelt Dispatchers TCS Members FROM:David W.Burlingame,Manager,Power contro1 > SUBJECT:Quartz Creek Transformer Failure Bradley Lake Unit Trip -July 8,1992 Enclosed are the plots of the Kenai Peninsula frequency and voltage following the operation of the Quartz Creek transformer differential relays. Bradley Lake was operating at approximately 75 MW prior to the trip.Frequency was stabilized by the Bradley deflectors for only approximately 23 seconds prior to oscillations ranging from 62.3 Hz to 56.7 Hz.The Kenai shed all three stages of loadshedding. Kenai voltages rose to 115%for approximately4 minutes,presumablyduetotheexcessofgenerationcoupledwiththelossofKenaiarealoadduringloadshedding. We have since completed and installed a program which willautomaticallydetectKenaiislandingconditionsthroughdifferencesintheKenaiandAnchorageareafrequenciesandshouldplaceone Bradley Lake unit in deflector within 15 seconds of islanding. The long time delay is required due to the transient swings in thesysteminwhichtheKenaiandAnchoragefrequenciesduenotcorrelatesimultaneously. Unit 1 would not initially respond to deflector control,presumablyduetoaproblemwithinourSCADAsystem,unit 2 backed off-line on reverse power after it was placed on deflector control. cc:Larry Hembree -ML&P D.Eberle -AEA File 410 Era.d (my FrBRpaTy PKMEMKAE FOIE - Q+2 mfr go.0 |etl ali aha te art etiam he en abet hata eta "ant them TaGH|f5474/od |e\1 \heY 5.rs /l qtcae”eat aeC610& og.13rd446 fe.- enka Sa)aM fms)Li 200 ,0 1200.0 1600.0 20 ti ous 4 Eradieay Ul MM Fee SIE FEGteh =Dez mene Fault a e 7°2.¢2.8 20.0 - o.oo 4 a red ff i ! .6:Pd nactnranet hed are ervete tT i v Petes tps ."20,04 2 ths Ananda PY tone wre Ae -4o.a-l +>i fi a 160 D ot Ero.d|ay Q+2 Ck =Fm im,7 "10,0- "40.07 "7 elo* om TS,_yetet,f"ft pal/ sareeyl 29.%C G00 mi mo,i et Py ct ue,at "t 6emu0.0 1000,0 1z00.0 ELPP &§39 KY Yolétage FeBvae EN sehe&QO wear +e ip Ba,a =79 a?elas! metwwt"vn '|.:ind iad a CY quell ""n ne tesa:'eo |ff };nfFNd/F i n,ft \rs|ae ; 70.0 Y V7 AN 10.18 "1 {alten au G7.79e 277 ec ,o7 Bey ye 00.0 1900.0 izoo.0 1400.0 O-Coa Csengph cus >pane GOo-fae J seng 4.eves VY fecond! Gos (0 Ef toyhe fury second sar Sane ytove | pres th Lond apart / _oo),/-§%o 006 -097 o'oost O'ono,arr ar oon s Fae"1 alamaaatriahaieiit Mien tank.ed eh ahaha Deeg ngDiy hee er scan naco 190)w&LOSSr' STES 1589 oss sooo pi,ta8S 7|opr Ji |i||'\|| wha,to RE 4 ,|uyHrT)\gil .err?u'!/.Abo)@ ef eI a 408%sity Att AWS TA -SFr oes Perte's HKruwBnibeast dd 4 {/©-_- STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUE Ri CEIVEDAENGLEWOOD,COLORADO 80111 -2137 on "an.Ql2oa ,7ADORESSALLCORRESPONDENCETOP.O SOX 5406.DENVER.COLORADO 80217 5406 ae ere wu Twx.910 935.0105 TELEPHONE 303 741-7700 FAX eet sosvom wa WU TELEX 45-4401 RCA TELEX 28925 AbbSkebe w=AUTHORITYCMATTANOOGATNO4eM1OGETa CHERRY mia mS D,PORTLANO aesitetaconfie©OECATUR AL &PLEASANTON CACENvEeRCO OT LAUDERCALE FL MOUSTON TE Tamra OL WASHINGTON OC RECEIVEDMr.D.R.Eberle September 22,1992 Project Manager OCT 86 1992AlaskaEnergyAuthority J.O.19239.21 701 East Tudor Road'-Power Conroy WP 26A Anchorage,AK 99503 SWEC/AEA/2910 BRADLEY LAKE OSCILLATIONS ON ISLANDING BRADLEY LAKE HYOR TRIC PROJECT At your request,we have examined the frequency oscillations that occurred in the operation of the Bradley Lake units when they were islanded while exporting power to Anchorage on June 3 and July 8,1992.The oscillations observed are due to the gains in the governor system.These gains were optimized for the connected condition,assuming that one unit would be switched to the deflector mode whenever the units are isilanded without combustion turbines.The solution to avoiding these oscillations is to put one unit in deflector mode before they begin.In both of these events,when one unit was placed in deflector mode by CEA,the frequency oscillations ceased.Using PTI's simulation,this action has been verified for a range of export levels. While we were simulating these events,a small oscillation and instability in the control of the unit left in needle control was observed.This is due to a gain acceleration function Woodward added to the governor last August.By eliminating this function,this instability between the units was eliminated. We recommend that the gain acceleration function be disabled by onsite tuning changes to the governors and that one unit be placed in deflector mode as soon as possible after Bradley Lake is isolated.As a possible and perhaps better long term solution,Woodward has upgraded their governor software to provide another method of positioning the needles that eliminates the high on-line PIO gains.This may eliminate both oscillations and also smooth out the needle transitions.We recommend that this upgrade be investigated. The following is a detailed analysis of our investigation,and conclusions. Description of Events June 3,1992 -On June 3,Bradley Lake was operating with two units and a total generation of approximately 90 MW.No other units were operating on the Kenai.The total export was approximately 40 MW.Due to switching actions by CEA,the Bradley Lake to Soldotna line exceeded it transfer capability (with the praesent capacitor configuration and no SVC's),the Tete 1889+STONE&WEBSTER =!vaypp00420.wpt/BL007 Ne er Aan Mr.0.R.Eberle September 22,1992 Page 2 voltage began to collapse,and the Soldotna-Quartz creek relays operated islanding the Kenai.' Approximately 63 seconds after the islanding and subsequent rejection of 40 MW,the Kenai frequency began to oscillate between 58.2 and 62.7 Hz with a period of approximately 45 seconds.See Plot 1 for a plot of this oscillation taken from the Bernice Lake Dynamic System Monitor (OSM). Five minutes after the islanding,Bradley Lake Unit 1 was placed in deflector mode and the oscillations ceased.Subsequent events caused the Kenai to again be islanded,and eventually blacked out.These events were unrelated to the oscillations of the Bradley Lake Units.' July 8,1992 -On July 8,Bradley Lake was operating at approximately 75 MW with only hydro units operating on the Kenai.Due to a problem with the Quartz Creek transformer,the differential relays operated islanding the Kenai.Following the load rejection,Kenai frequency was stable for approximately 23 seconds before it began to oscillate between 56.7 and 62.3 Hz.Unit 1 could not be placed in deflector mode due to a problem with CEA's SCADA System.?Unit 2 was placed in deflector mode approximately 4 minutes after the islanding and the oscillations ceased.See Plot 2 for a plot of the frequency taken from the Bradley Lake OSM. Analysis The oscillations observed were predicted by Woodward Governor (WGC)in their stability analysis used to derive the governor gains.The governor gains for the connected system were optimized by WGC to provide maximum unit response.This results in gains that are marginally stable when the unit is operating isolated and produces the frequency oscillations observed.A trigger was originally provided to switch to off-line gains.This was later replaced with the deflector mode. in April 1990,a Load Acceptance Analysis was prepared by Stone &Webster in response to concerns that the Bradley Lake units would not be able to provide spinning reserves to the connected system.One recommendation from the study was that a "Deflector Mode”be created that utilized all six needles and partially cut in deflectors.* This recommendation was accepted by AEA,the TCS,and the PMC,and subsequently implemented by Fuji and WGC in the Bradley Lake Governors.Woodward also optimized the on-line gains to provide maximum stable unit response for spinning reserve to the connected system.The Power Technologies,Inc.Islanded Operation Study discussed the application of the deflector mode in detail and recommended that one unit be placed in deflector mode Meno from Dan Rogers to Devid Burlingame dated June 9,1992. 2 seo from Devid Burlingeme to TCS Members dated July 8,1992. Speport on Load Acceptance Analysis deted April 1990. pp00420.wpt/BLO07 Mr.D.R.Eberle September 22,1992 Page 3 whenever the Kenai is islanded with only hydrogeneration on line."The TCS reviewed this and concurred. When WGC created the deflector mode,the isolated trigger was changed to the deflector mode trigger.Thus,the gains are changed to an off-line set in the deflector mode to maintain unit stability when isolated. After these events,CEA has implemented an aigorithm in their SCADA that determines that the Kenai is islanded by comparing frequency with the rest of the system,and puts one unit in deflector mode.This will happen within 12 seconds (verbal from David Burlingame)of islanding.This solution left the question of whether 12 seconds was sufficient to avoid the oscillations. To determine if this was the case,PTI ran simulations at O MW (Plot 3),10 MW (Plot 4),20 MW (Pilot 5),and 30 MW (Plot 6)exports,without a Bradley Lake unit being placed in deflector mode.In each case,the oscillation does not start until at least 12 seconds after islanding,14 seconds for 10 MW and 24 seconds for O MW.Similarly,two import conditions were tested,3 MW (Plot 7)and 5 MW (Plot 8).The 3 MW case hasa first underfrequency that just avoids HEA's first stage of load shedding.The 5 MW case would cause first stage load shedding on the Kenai.Both cases begin to oscillate immediately after the islanding. Each of these cases was rerun with one unit at Bradley Lake being put in deflector mode 12 seconds after islanding (the current system).For all of these,plots 9 through 14,the oscillation is prevented by use of the deflector mode. In these simulations it was noted that for the 10 MW and 20 MW export cases,an underfrequency occurred that would most likely cause first stage load shedding.This is due to saturation of the needle PID of the unit that remains in needle control.This causes the needies to close at maximum rate,overshooting the steady state point and thus the underfrequency.in an attempt to prevent this underfrequency,simulations were done with the deflector mode being implemented when frequency exceeds 61.5Hz,significantly sooner than 12 seconds (Plots 15 through 17).These plots show that the sooner the unit is put in deflector mode,the shorter the time of saturation and which in turn reduces the undershoot to acceptable levels. An additional oscillation was noted in these runs.After Unit 1 is placed in deflector mode following the 30 MW load rejection,a smaller frequency oscillation,<1Hz,occurs (Plot 12 and 17).This is also a result of saturation of the control on the unit in needle control.After discussions with WGC and review of the governor design,it was determined that the saturation is due to a PID gain accelerator function on the needle PID which increases the needie gains for large speed errors,increasing the closing rate.This gain accelerator is also responsible for the fast closing and resultant underfrequency observed above. To verify this,cases were run where this function was disabled (Plots 18 through 22).These cases show that disabling this function eliminates the second oscillation observed,and also *'Telanded Operation Study -Draft,PTI Report R21-90C,deted June 18,1990. 9000420.wpt/BL007 Mr.D.R.Eberle September 22,1992 Page 4 prevents the underfrequency and possible load shedding seen on the 10 MW and 20 MW cases. In evaluating the simulations,it was noticed that the initial overspeed in the simulation of the July 8 event (Plot 23)was higher than the actual.After investigation,it appears that this is due to a difference in deflector effectiveness for large needle openings between Fuji's turbine model test results that the PTI model is based on,and the actual prototype turbine.This difference does not affect the oscillation investigation in that the oscillations are a results of needle action and closely replicate the actual event. Possible Governor Modification A.The purpose of the governor gain acceleration function provided by WGC was to increase the rate of needle movement to reduce water wasted and turbine wear on large load rejections and increase unit response to large speed adjust changes. Eliminating this gain will let the needles respond at the normal on-line gains and rates, avoiding the underfrequency and oscillation with the other unit,and generally improving unit stability.The gain parameter has a field adjustable multiplier from 0 to 5.To disable it,the multiplier can be set to zero.In addition,there is a field adjustable error before the gain accelerator takes affect that can be set to its maximum valve.These changes can be made on site without assistance from Woodward. The disadvantage of making this change is slightly increased water wasted and turbine wear due to the longer deflection and slower response to large speed deviations.For the 30 MW rejection,the time until the needles and deflectors are equalized increases from 27 to 275 seconds.This increase in time is beneficial in that the time before the oscillation begins,allowing more time to get one unit into deflector mode and increasing stability in the minutes following the islanding.Without the gain accelerator,the needles will respond at the on-line gain rates,slower than with the accelerator.This will only be noticeable for large load rejections,or extremely rapid and large changes in speed setpoint.Since the deflectors will have control during load rejections,and speed set changes only occur at SCADA pulse rates,the effect of this change to operations should not be significant. B.Woodward has advised us that they have developed a new governing scheme for needle positioning.It eliminates the high on-line gains and provides a feedforward control for needle positioning.They believe that this new control would eliminate both of the observed oscillations,and also smooth out the needle transitions while providing maximum response to speed adjust changes.We are not completely familiar with the changes WGC has proposed,and can not make any recommendations or give assurances on its performance without further study. nclusion The oscillations observed are due to the high connected gains being used when Bradley Lake is isolated.Placing one unit in deflector operation prevents the oscillations.While 12 seconds is adequate for all cases tested,the sooner the unit is placed in deflector mode,the more pp00<20.wpt/BL007 Mr.D.R.Eberle September 22,1992 Page 5 stable isolated operation will be.Underfrequencies and contro!oscillations associated with the needle control unit can be prevented by disabling the gain acceleration function in the governor. R mmendgation Immediate: 1.Place one unit in deflector mode as soon as possibile after Kenai isolation with only hydro on line.In-erder to reduce the 12 second delay,investigate possible changes in the way CEA SCADA detects isolation. 2.Disable the governor PID gain acceleration function at Bradiey Lake by setting the "Integral Scale Gain"to zero,and the offset error to its largest value. Long Term: Investigate the long term benefits of the software upgrade proposed by Woodward..This software has not been implemented for any other projects.If it is considered by AEA,we _recommend that a model be developed by Woodward,and independently tested by both Woodward and PTI to verify control stability.Woodward has indicated that they would require about three weeks of effort including onsite testing. We hope that this examination meets the needs of AEA and the TCS.If you have any questions,please call Mr.John Yale at (303)741-7433.; Theodore Critikos Project Manager TC/SBY/rji cc:TCS Members J.Doudna,PTI Xe:Kree wolf ECECRLE 99004 20.wpt/BLO007 Plot 10 11 12 13 14 15 16 17 18 900420.wpt/BLOO7 INDEX OF PLOTS ription DSM at Bernice Lake for June 3 event DSM at Bradley Lake for July 8 event Simulation -O MW Export,Islanding Event,No remedial Actions. Simulation -10 MW Export,Islanding Event,No remedial Actions. Simulation=20 MW Export,Islanding Event,No remedial Actions. Simulation -30 MW Export,Islanding Event,No remedial Actions. Simulation -3 MW Import,Islanding Event,No remedial Actions. Simulation -5 MW Import,Islanding Event,No remedial Actions. Simulation -O MW Export,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -10 MW Export,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -20 MW Export,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -30 MW Export,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -3 MW import,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -5 MW Import,Islanding Event,Unit 1 in Deflector Mode 12 Seconds After Event. Simulation -10 MW Export,Islanding Event,Unit 1 in Deflector Mode when f=61.5 Hz. Simulation -20 MW Export,Islanding Event,Unit 1 in Deflector Mode when f=61.5 Hz. Simulation -30 MW Export,Islanding Event,Unit 1 in Deflector Mode when f=61.5 Hz. Simulation -O MW Export,Islanding Event,Gain Acceleration Disabled 19 Simulation -10 MW Export,Islanding Event,Gain Acceleration Disabled 20 Simulation -20 MW Export,Islanding Event,Gain Acceleration Disabled 21 Simulation -30 MW Export,Islanding Event,Gain Acceleration Disabled 22 Simulation -3 MW Import,Islanding Event,Gain Acceleration Disabled 23 Simulation of July 8 event 00420.wpt/BL007 fi iy2 Teo|Oe]jane nap aa .ite ed cowmcamenne a.a eae.atte comdatedl mace ditty etinaiantet hiatal soe oy tata |.Pees ae aw mane -r ane bean te ee camhemeemed ll | (stsu)soy ores a mest G4 9 078 {yo 3 3 |(53971)6 -) 'vels =f |||(29)ALE <?, wonton alata 4 +-sofas anitfwoeeelAlol"ull |LSet BLT.8.len OTOF oe Perera mat f'04 fi ee n ,{|lw Ly aantf bai i (en)22 1-7 023 (ste50)Gro 99°29°°""} (Sse)+a ce | Caz9-€9 sy Or@.<@.Ge 6 OO mene sO.@ 4 1a 48 O02 Dom. ©OR OOO FO.DD MOOI STUER GFR ON CRUOEIe Oi 8s Oe.8 e 848 Ow &8 he |De el ee ee etPd ee Cr ne,YY ee Oe Oe ee |0 DF OLR Ane DENN SOO OG ES 0 Ue 6 PLEA.CCRERYLOE,eed PO TR eB mec YY Beer Dkhe Eo Pe eee ee ee Oe aia TOE ead |0 RR COLA CAS'auaem wovatasevvmragaqcans re:sae -ONS See 8 eR ee 6 OED G6 UD evtimnrtred 8 0 8 OD0 OD NE6 OOD OA as "O16 Osu.wd ep wO.EPOe aEZH=2-0 a ceedGSPCeamtOnrareFIUBNEBA"m4 ddld Tare te/€-)PLOT1-JUNE3EVENT 4s Xta -92102 26/70/74 Rouenbeusy KOlPoun o'Q002 0°009%4 q'gozt ,etre '6!00h '0°0 5 Loves ged | pSst .ye?ety a |398 waved oP OS oes.fFPpo'ss oe f y gbhep?hh GS u ,0| 2? pAatenwrteastetmttarteh sore Pobre einen itl ert SEN EAOANS He o°ot ,= "tee .ge?| ;200 9?zi77 L.O°29 :+t ar 9o*ot?oe?'"$4219%=ue?oth 917 509%/§ yae™:»y gst? } SNOILOV 1VIG3SINSY ON- LYOdX3 MIAO -€LO'ld SANIVA 2 ATIC Cores 2661 19ae"mas- n mevve =war2 emse'sis-in=iv1(ahaReeaneNaefeeleeeeare|L a peo TER ; i£ oO fT RTE Ie Pd bissotE - 7 RES5gue 747 7 bee __. Lae - rame newest acne Bee2 ', o a.aeae "seed fas Seewer” BRa L " i} EERE...)yyyyy SaANTVA T# AdTICWwud Seted 2667 1¢GBS "BRE geo'va, een'se (oes)paz onn-o owe-? _ . . onsrt eL "ERE ER y |IJ yOothtPpil:popitana1BB TILZ:SON-NO.CHY SOUR WOR LOAD.BRADLEY @ 52.Sect,Com KzMal BuPORT. TRIP CAVES CREFH-OMLVERSITVE DISAV LIS @ T =1.0 sECOIwS. KEWAS SVC'S OUT OF SIRVICE. €O ADGDIAL ACTiowe F ' » 4 é A 1} ' \ lu haa {. 13.0000 L [Tertte T3053 63.666 ne = al 2©9 Cee SNOILOV TVIGSINSY ON- LYOdX3 MIAOL-»LO1d SZQWA 7@ ABIAVUAEnitfiok iaebe7ith - ar E ls i"ui |CREESAOT¥A £t# ABIOWUE estee 266% 10@as °aneEEEFER EEyEOEEERa: ELE ry-3&Mh "at &see2gSBERa5iafits | ui) BREEE oO SES 4 qm erecceee eya eseaeooe ' A4A ' \ ' Soo” "\ \ a2 =m oe oe0'57) = -_ o4:00t} onset! f i *CROIL Tt"eamosas O°@ £8 207 ANGIT S1I6CAs18O-UETO 8 WR TIN UT WES UL mad°eza-woe 14104 - Qronwwnrey @n aoe we isiTOE. SEP02 1992 68:56 BRADLEY $1 VALUES ge 'eettFELT WED OEK-0S RITA TVA. ae01 1952 00057 BRADLEY #2 VALUES PLOT5- 2OMW EXPORT -NO REMEDIAL ACTIONS SNOILOV IWIGSINSY ON- LYOdX3 MWOE -9LOId S2QIWA 2% XITTOWUG $5100 8661 10 eee"ansTos:sors cor SiNeGR woeos LOAD.BRADLEY @ 06.S0t,Hist KEWAL Exrart. RENAS 6VC'S OUT OF SBAVITS.TRIP DAVES CRELR-OMIVERSITY LLSKV Lies 8 T =3.6 SECOUNS. m0 REGDIAL MTIOMS.= (50.8 (6.060 1h,b0 Z SAQ1VA T# ADTOWUE VSteo 2601 Loape "ans - ;iPOEREE° cht? . bg eega&3 TELZs suw-30.cop 3.02 Ae Be, GUORA VOR LOAD.BRADLEY ©U6.De.J0me EPBAI EXPORT.MENAL SVC'S OUT CF SERVICE. TRIP GAVES CREEN-OBIVERS!WO REMEDIAL ACTiONS. { Ay?mS) {W $1.6000 { {le.ese { fred.ee | 163.606 red SNOILOV TVIGSINSY ON- LYOdWI MIE -£LO'ld SSOTVA ZO XB1ONUG GdITT 3661 TOame"OALwoe wn Ommart won one's 2 fe fe be 5 JJT- iw4 O eee ot Serre emmenny @occcevcocecve 4 "Few | -->--aee @naapampea=p ape epee ap«=mepopoweeeapaapond Y DAVES CREZR-ONIVEASITY 115KV Ee @ T=1,6 seccerS. FILZr suee-33.Can | j PEMEOIAL actTi0N8. SUWERVOTELOAD.BRADLEY @ (9.201,De Kal Dos.KBMAT SVC°S COT OF SERVICE. TRI wo q { ote ateate ate 100.40 W.aa (TT Ted.08 be SANTWA T@ ATICWU OVItt 2667 te23S *Mns _ . Ges) was PILRe SO 13.CHNOfbREER J... SNOILOV TVIGSWSY ON- LYOdWI MWS -8LOl1d GaOIVA Té AalCwud Deree Zest teawe"Engwee =n One nen one's - « anore ene°ss onus <7SanSO Kj bed ULNyLJ' rd o XC, i mt a J ie > otk-9 i - = oeEdSsa* bee ont ond °:5 , 'BE- ¢% ome 3589 a '' / 'FE&" ri ' yy ' 7 Jz ' e . , ' " me "ee ' ry o * Lap ae ' H ' 7 e %o \ a| e@ a” es o na a ow et” _ aefis L UO OEREE1?££E |e Ce |a SINTWA T@ AZICWUS (oes) maz 60°60 Test teake "ane ilai:thkiimaaa ad? 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Te aee Cerawe eee ee ee Pod ° o osere Pewcesce - *. oe Correo,@ F =13.0 sscoNDs.ViSev tres @ Tv ©3.6 seCcoMDs. ae » o Ay -_ PROGR WORM LOAD.BAADLZY @ 63.500.LOWS KEMAT EXPORT. FRE:30e-01 boF.CoN td Ad 's 8 e e oe KemA?SVC'S CUT OF SERVIC.TRIP DAVES CRESK-UN)VERSTTYRAD@1SwITCRED70DBSLECTOR . o " oo BefeykFEEESE 14 tL ,} lii1| SANTWA T@ AVICWUG ™ . ° (ces) MIs 42:60 366T 20eRe 'oun "en =. wn nt, EEeeEe-TT rnee -- T_ T,” | LJ - Secvocesers POLE:weee-xiOty.cH TRIP OXVES CRSEN-OWIVERSTTY1)90V LIBS @ =2.0 BECOMES. CRUER WH)LOND.BRADLEY©63.Sem,10pe KEMAL BXPORT. BAAD$}SUITCRED TO DEFLECTORCONTROL@FF=13.8 sECROS. KEMAL sVC'S OUT CF SEXVICH.ubEee7 L _ ond on oop | ae| eoce 't)\ ence 1)' "iA £0 100 6.348 Iu|*SMOdrE Tween sevel Smal |b ATOM 'CVO!Mine Caens | mad°aceri-moe MIS"Sqeocas 9°C1 3 6 1O6LMOD WOL>FT 290 OL Cis Ling 12 ON"SQN0ITE O°1 =LB UNIT AMET!AlIsuZAIG-NITD S4aed dtul i)at)1. ' }i)orHn orYoudgyof yeadpasEitaas ' ° . (ED, SUP02 1992 06:26 time (6EC) BRADLEY #1 VALUES "Tt TvTtTJYyy 7a:aahid78FHy - anf i a - ate Q - - m! Pa\ owe 7 3 \ A " o YscLee <° a ¢ = Neem eee -=--_- o_- -wnenawoe«= wa = Pa " re 5iEPEELie]zai§aa "gcmcoss O°ET @ 2 8 TOtImOD WLIGT SH OL CMH AS (¢Ted*pomooes O°C =28 BUT ANGIE ALISwIALAD-FTID ee *PHOaKE aren Wk PPS, 4 Le 4-- Thea gg - nal -L | a _ ma(320) "en"oe WED, SUP02 1992 00:26 BRADLEY $2 VALUES J PLOT 11- 2OMW EXPORT - DEFLECTOR MODE IN12SEC 93SZLNI SGOW YOLO31S350 - LYHOdXa MWOE -cL LOld SINTWA ZF ATTIOWUT S800 2661 80ane'om"EWoresceon eweea eedeose - 300 REMAI EXPORT. LiSxw Live @ T =3.6 sBCcOnDE. FILBt 90-LI00T .CiNBRAD81SWITCHEDTODEFLECTORComTMoL@ fT -13.0 seCOuDSs. Steer worst LOBD.BRADLEY @ 06.Sem.EEMAI SVC'S OOT OF SERVICE.TRIP DAVES CREBR-ON VERS ITT 115.000 ©GHEEE |106.00 SaNIWA Té STICwuE 2:00 366T TeauB 'oun . ax) wns EERE ERO liLD & a oN ; .ff tot oof. ,. ' : Eee:ititr >.-aH - ./ ams, 7] i7:y;: jao sean ” \-oS Me te? aB°”'7 bd } :it aN VV ae: wot oc q aaaee TOREo i coe "yd 28r] bes a penne Pennennwencewee > eee :7A .ge”4eefirKEMALSVC°S OUT OF SEXVICE,ye { RS) bse bee bres hremm bars i ean + JASCLNI SAGOW YOL93194G - LYOdINI MINE -eb LOTd S320TVWA 2% XAATAavud ceo 2663 seae'aan| Trwer eweeccaeeoe Seveavae2**** ern *ened eeneindednean "ey . ; VILe:8On-1307 CK ae e 4 *3 COT OF SERVICE.DAVES CREEX UWIVERSTTY 115KV LIME §¥=1.0 SPO”HDS. WOW LOAD,BRADLEY @ 09.3007.DO KEKAL [@ORT. $1 switcato To DETLECTOR COWrmoL @ T ©13.9 SECURE. WEA TRIP BRAD I J | BR zLWiE205l! [| 1!! a Sa2OTVWA 1% ARICVeG osteo TEGt zoeas 'om worse a (ope)ats won me's zEET Suites Guaee!anenek GEEGO|ms etyr4 PERE a CE pecseeae ee” 7 : rf _---4 A | 4 ' ? ECccwevny ae? 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SOTA FORM LOAD.BRADLEY §97.21M.See KewAL THrcRt |TRIP DAVES CREZA-Cwlvrast(ty 1\1sav Lime @ ¥3.0 SECONDS.BRAD #1]SHITCHRD TO DEYLECTOR copTROL @ f =13.0 SECONDS.PIL:sweISpr.cre XEMA]SVC'S COT OF SaRVICS, EEE - 13.00 Ch,0000 {4066 t Ss s - - bee l t I 2HS°L9=} ® YOLO31430 - LHOdX3 MIWOZ -OL LOTd - SZOIWA 0# ATVI Stt 266 30aes'omuv) marx onn°ee qeree oon ; eoo-ut . coeeo . a 7 yu Ldod woes. ques a LM 2 le . TTTTTTT Tv. T- p> . >o e e e e e ° ° e pane e e an bdee rr. é¢444l= oq e -ff obit on .80 "A ° * ”-ew a PP ciate eo .weoceccecoece @ SeeMSOSON COmpaweee? * o *. f * Co rd 1 irit betad >=o = - =omape 4 ' _- a4 Bia: : - FILE:8 X20072.Com CUKIB-COUVERSITY 11lSeTvCRRDTODEFLECTOR CONTROL te] -0008 1.0000 38,96 60.00 BEE EL +»4ty tf yg yl yg SS0TWA 1% ATIC (as) mr ; Tlstt feet coane 'cm we ann eneres euo-ts qo-et =n even 8 EERTREER en DaeeeOeeeeseeeeteoe| > eo i ' a ' ond rtae | ots, : ' 'H a td ae \ : _" : ' ;!pr emee wee, oo "fe -ome A', -- -- -a --_-_re -a.oo aN CREAR-COLVEASITY ILSxv Liwe ¢€Y ©1.0 sacowwS. PIL2:9-x20062.CHNSUCTOWDTOOBPIZCTORCowra.©61.5 EZ. SUOEAMORNLORD.BRADLEY@Tie.20a KEMAI Enron'.KEMA]GVT'S CUT OF SERVICE.TRIP DAVESBRADLEY$1 | Wh. i d.64606 L [2.9000 ZHS°L9=3 © HOLOAISIG - LYOdX3 MWOZ -9b101d':SZOWA 2# ATWvUs (ws) merz Sttlt 8667 30aes'omme _ wee mw OP *=n.-;i a aanineiti a§t >» fef FILEs 8-X200r2 CumiSwTICWEDTODEFLECTORCONTROL @ 61.VER CRESR-CODVERSITT LLSeV LE Eze 3gve's cur oF éERVICS.BORN LAD.WATLEY @ IK.Powe KSRAL EXPORT,iasxit-L!is mi"i es es eeee| keeeineents extn SAQTVA TF ATIGWNS TI8tt beetcoame4 ones an Ow!auvt eves fe Te Te T ne T1TH > je é L i . : * : ae oe . i:,if poem coe "re ee, oan ro ;H ' H - aom --=Fe” oT JN IqSOUTOFSERVICE PILZ:9-x20062 Cut CRERE-OBIVERSITY BLS LIWE @7 -1.0 sucmms.BRADLEY @1 SUC TCHED TO DSPLECTORCowTRGL@ 63.5 E2. FOOERBonLOAD.BRADLEYKSMAISVC'TRIP DAVES } pL) SO@CR WORM LOAD.GRADLEY @ 52.S5om8.OP0 KENAI RBXPORT. RENAL SVC'S OUT OF SERVICE. TRIP DAVES CREER-OMIVFRSITY LISKV LIWE @ T »1.0 SECOWDS. MO REMEDIAL ACTLOWS ON BRADLEY. FILE:S-XxO0.yDEULTEDPLOW{CPS}1950.06 .<e.ee ob 6.0} |PET LACTOR Posiriow sry)|11.0000 rs 6.01 lt JAOCEST_EING OFTEIRC ro)|Ji .oeee ===e @.0} |&OF ACTIVE puaies J[10.040 ,eee |4.0| |PECEANICAL POR USN a[100.00 ---¢0.0] {163.000 sa eee!rnAa«@ aPala> "+4 ss ee 4 ofBs a [7 SUNOEER WORM LOAD.BRADLFY @ $2.Sam.Ont KENAI EXPORT. KENAL SVC°S OUT OF SEAVICL.TRIP DAVES CREEK-UNIVERSITY TISKV LIME @ ¥©1.6urJNOREMEDIALACTIONSUWegceaFILE:&-x0.CHR L FACTS PE TS.J [750.08 re |e.e] PSYLECTOR POSTY1 ow cy)-| 7).e000 -----=e ee] LARGEST SEXELE OPEXIPG_(V1 | Ja.00ee Bocce ---8 o.e]- L t [ie 006 -"-< l SRCHANICAL POA.oe - J)00.¢0 ss 1 }yearn T ”}Lf |} eTe eteLmebh)eo ”oo”|orm 0”t =7 ee See | .me,eee I weer”won"7-7 o”| --ry =ws Fe mee me | e "". » -7 P| -----"wor".oo e *.| 7 =.ee -2 :oY | a ae aan |'oa 7". ”2 .wel. .| .e -77”or |-a oo t a "AL Sey ( ".' =7 ¢|3 ae ”é oon t 'J \' -s 'j e a4 i AY ' 'é ;{ 'é e l j |,|}Bi {'jy tt!l :60:36qarrirvescr6@1992Tee,RRANT©TVv4990.006TIME(8£C)IAT12aARALPVsnnme 2ene-4- [---|SUPOGR WORM LOAD.BRADLEY ¢63.S>0¢.10001 KENAI EXPORT.{77771 SOROER WORM LOAD.BRADLEY @ 63.Seem.1008 KENAL EXPORT.°rat KENAI SVC'S OUT OF SERVICE.=u!Wann MENA]SVC°S OUT OF SERVICE.$-1.0 SeCcomDS ° )TRIP DAVES CREEK-UWIVERSTTY TISKV Lin @ T ©1.0 SECONDS."dt TRIP DAVES CREEK-UMIVERSITY IISKV LIWE @ .. = NO REMEDIAL ACTIONS ON BRADLEY.'Lao},HO REMEDIAL ACTIONS OM BRADLEY.,bs PILE:3-x10.FEL2:$-K)0.CAN -I PROMS ID Fe ice st pws ad[t3¢.¢o |Serer 5 Ory |2?F =|karLectog POs7199_ipot jI7 "_CMrLacTs®F108 icra)---[1.0000 rere 3.01 ==[730.00 ¥W ai s|LARGEST PASO OFSF IPG iP9)!|PSI MACTOR FORINT AV__--[T.0ee0 SSS eel S24![Tove ==.v.04 5wnfl]}}fOF BCTIVE pezDiAs +43 ee ==8 O00 og110.300 @er--s oe ee}nN [7.0000 Sececen 04 eSEPLCAL,POE OW)j BS I 2.OF ACTIVE UES --,-{[100.00 ---FT 6.6][36.000 ° { [peoaity 11347 rego fz);I FUCA ICAL,PER ON 4 162.008 o-----T 38.000|ToT)-o.el '=ee SO aes SS OS OE a -e .°2--*-°?wey a 2-707 neg {_3 -wT ee ween,'4 -'7 Pe. Ss mee wren ah-_ewoom wore |ool we See,">>a - -w 0-weor -oor" =a mee J =a Nodal x.tne'| ,or <2.| =_ ,-or77 a '- wee ce |nu -a"oo?-e | -Sey -2 - i - *of aSL e | -?e . a .<an | ® | i]q Ly =!.|-F)yD-°\"'.1:4 ,ee es eePe?Lae !SYionteoeam/emeneaoeeo---- 220.CEN 415 eo")NO REMEDIAL ACTIOWS OW RRADLEY. FILE:S- SUPER WORM LOAD.BRADLEY @ 7Semt.20088 KENAI EXPORT. KENAI SVC'S OUT OF SERVICE. aA TRIP DAVES CREEK-URIVERSSTYWann-t Te]p23)9:5s i 0 eeeEee1738.00 mwww=me11.0000-° Geceope oeJ1.0000 eTe|a)£ J 100.00 , (328) @nIl porrrey veer on"oteed wove? 'y geen ea soe°er-4 TT|'{'l| to: re mem ee tt fom, ort, :_---re ie mee :4 a _ Pw eae ee Tt ee wer ee Paeewew, . see . . . "4 - --=- a oon o” "-_ _-mnmr one eT wwe. ewmow --. 0” ' ---_-- =eeeeeewaweweweeaweweeew EO eeeeoy4 ' ' = .) = pam -_q ||J!Jf{J Jo... SZNTWA Té 96:65 266% 90daé --enr 208 KERAT EXPORT. T =1.0 SECOMS.Tw, 32. 195 FILE:S-x70.CreN v STROER WORF LOAD.BRADLEY ©75enr, KENA]SVC°S OUT OF SERVICE. TRIP DAVES CREER-AMIVERSITY WO RFPEDIAL ACTIONS ON BRADLET.= AGTOWaS "and CER @°oe-----me 110.060 qu eeGE (348) wir _, beo-os oveee oonoc ece-et . eono's |||yl]TT en ee 2ar ee a "weer ® o ' .. 7 e a "ee ° . e -.. a - - ae - mee eee ee el \ pa V4 pw tre meee LL ay a ww aren mn 4 ee oe ---F$ FCCSEETHRSOSCeden ewneeeeezece Qeaeceaecanavaecee @eee wecccerle 4 2 wen 8weemat wweww SUMMER WOR LOAD.BRADLEY @ 66.Sev.JOMM KEMAI EXPORT.=Annn-4 RENAL SVC°S OUT OF SERVICE.mu”TRIP DAVES CREER-UWIVERSITY 1)©7 fa)|GaE=-JWO AEDROIAL ACTIONS Of BRADLEY.E pao) j VOLE:$-030.CHe a Han PEF LECTED PLOW sors)lnk1790.00 arr ererers5 0.6 |a> POTLACTOR POSIT 108 UPD jl "41).2009 Ber eeees La 60]om|AAREST EDL OTeN BS Fy?|[1.6000 aT)0.01 neyfOFACTIVEmapias}4116.000 reese 6 0.0]vey F MACTBEICAL,POM Ost)=7 .|5100.00 =-_-6 a 163.000 DIE a eeieeeiot=F --i =a ': a Se tcfindin8°2°°Tee eaee fe 2 aerarer ; i .Perrrre:3 eee we aya =--..aeee eee,a *' _3 2 t | A4 =4 4 'yt, .g -¥'[a =t ' | ' tL) _'3' '3 r i) t -' ' o t) 9 an on '3 t 'bY |: t a t ° SUWIER WOR LOAD.BRADLEY @ 86.Se0f.300 KEMAL EXPORT.Aw KEMAL SVC°S OUT OF SERVICE.D4-TRIP DAVES CREEK-UNIVEASITY Beene -ogJWOREMEDIALACTIONSOWBRADLEY. TILE:$-xOe.. ,a }PATLECIE?08 1K aa (130.00 oe ee ¥a 5ROLEPOUTIOPOviIy.0000 SS oe oe JLARSSTSEESOFSPo?.bseas --------U vol sg f OF ACTIVE PERCLAS |¥ [10.000 e-a aPECTORAL,PR Be)lise-as -6.@ | ene ae 3-5-5:lake ele BEwaeewwee”"TT thittits Cle 8 22i5grr 7 £oiX 3Socreately-ss2 aw =ee _--Seat "”? }'2 _7 :z', i' 1 ;Is '5''3s AN *y ]A 8 CdLae';. j ': 14 : -:3 r 4 ;3 0 a }o4 /?a e s(':]' F boa gy fy {'i”d *,[l J 1.j wb neat "!ne Sees OOO: ee TRIP DAVES CREFRK-UMNIVERSITY 115 SUMMER WORM LOAD.BRADIEY @ 49.Jo.JNW KENAL IMPORT.,KFMAL SVC°S OUT OF SERVICE. Y -1.0 SECOMDS.ee)NU REMPDIAL ACTIONS ON BRADILY. FILE:$-19.CKN 'FT}] 1796.00 |ere >e.0| {___9M CTOR Pos rio tr __|It.@600 a a oe| 'LARGEST _BEEDLS OVENIRG _irvl J[t.e000 on we we 0.0] {£OF ACTIVE SREDLES _)116.@60 oowvccee °o.e | |ECHARICAL FORER.Ger?i][100.00 e- -s 0.0) |genoigy_li2sy rea can ___-|fe3.e08 ----s $a.000} I 78se3 a -_]¢48- fee =_B is wad ” ®Lene "a bd% ” a 4,.y Pad z=out *ve,3 7 : fy -SEP08199239:99BRADLEY#1VALUESTUE,TIME(SEC)Ce eee ee Enmaenete SUM@@ZER NORM LOAD.BRADLEY @ 49.2000.J KFHAL IMPORT. KEWAL SVC°S OUT OF SERVICE.Ka]TRIP DAVES CREEK-UMIVEASITY IESKV LIVE 0 TslarJ]NO REPE.DiAL ACTIONS OW BRADLEY.FILE:$-13.CHW |POY LaCie rie Core | [T3000 Tes .6.04 I Derlacvor fos Iyi08 irv)__| }t.6000 ---=="wlLAPGESTBEROLEOFSRIPSPO)-Scrsseris ar §_OF ACTIVE FEES __|110.000 ema WCIAEICAL,fosEr oe)----_){100.00 |{i Ry f yI t | wooo”7a--4*="ee wee, se |"e =--?on b-ocr”AgweI."mee ty ?|!--a? eryee ee,a.* - ”|o”wow oo”<4mMrs,- °ee _?'ianoor,ae . 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SUMMER NORM LOAD.BRADSFY @ 49.Jrar,rm Jent KENAL IMPORT.yw KFEMAL SVC'S OUT OF SERVICE.a ” =-"TRIP OAVES CREFRK-UMIVERSITY 115 Y -1.0 SECONDS.oo fa]bE)NU REMEDIAS ACTIONS ON CO $9 FILE:$-92.c1w 3 }uu as.[730.00 rr rere >eo}SF |Sr\ector posivigs iry }"o4Th#000 Pes "*0.01 Swe|LAPGRST MEADS OWEN ES ord j[1 e000 rs =0.0]fh >a hh)_f OF DCTIVS prepies 4+[16.060 ees oe) l __RCAAKICAS PORER_oer)pa[100.60 -----<4 0.0){_-_EOLAT_114Y remo fap ;[63.000 --- e $a.000 | el:fee e ?-o”'”',.3 Le ° "bd3 oad $ 5 =TIME(SEC)|]SOMMER NORM LOAD.BRADLEY @ 49.Dat,NO NAL IMPORT.Mn]RENAE SVC°S OUT OF SERVICE.=tEa]TRIP DAVES CREEK-UNIVERSITY DISKV LIVE Ts.a:lesJ]NO REMEDSAL ACTIONS OW BRADLEY.°;FILE:$-13.CHN i?asa I DOT ACTAS PUG (OB _|"«[730.06 ra .el se |periactoe eos trian sro -|a;[1.0000 -----o.e]atMAPeR3TWENDLAOTEPG(rol -|.»[4.0000 Perens =-8 0.04 BS{-§_OF ACTIVE werriEs -|&F}10.000 -=---e.e]t|WECUAZICAL foes gen J 1100.00 --s ee q I |CT ty f '|if 7 woo”*. <2 J.8 -meme wey 3way|« e -e a poor errWemTes.7."4wo?|Po 3L. oor™77 .id 3 sweewee,">OUwae -a *be)(wee Ios.i) -'&-=| --"te tyas¥3weef-.at 3 | - >,annoJof5 7-ow o tee,\Pannst |3=*'oad 7 ee ee 4 lfe2ia?o-*.4adoe° wown oo?"=°°$|_.'«|:mee ta Zz HebYy|oo”o” L were |4! (,- .'{ 5 e *. i J } ,J]l Ls,1 |I {<oe.ae== --_---wwoes(33S)12Shen ...jh eee,eww eee _B}..--°°toto lialeeresoWe ZIlize shoo”Smee |' gj...ene |7 o**ee 'eirrT a ria! eco _- Nolin ! tor Trrz.tae| a= ” rr t See =2.!!eds eee Rn SE | pee ---00°001]if TSS VST VES } Lee o-->e0e-or| [Wired DYIWw ss 7 (ee eevnceuos coco"tfifVDSELPeTE} tere em aw om ==O eonot{is Te OTIS CLIT | je _co o0°ose)} & MHD 26100 STIs*ATlOVUR WO SHOI LIV TVICRAM Of v "Nault ALwlosl °3ES O°1 =2 8 SOR ANGIE Magw BinvNd dtuL "L4O0KI IVNIM peise ae @ MZHOOD °0L OL BD ATICGWUE "SMOILIGNOD 26TACHD|"OWLSSQIVAT@AITO62.0«266%£0Sasaan =-""s oo peer eeers _Zi---é::'panera ovary ° -=,_-tT.7 Ae weome -_eoseseeenreewebocvwe t =2.<}i I,mee -!aoeosceoge '®cleeo°ae Me 1 :-- Se "»-ween,'po -_Ss :wey 0”reer?'an?is a i e <-<-EE,'ne”Se -arene :-_.oe q en ose,_ =a_-Teeny sfawea>”re :al,er'a "wee,a ---3 Ss -eee 'pe Pr”ae a we?oe.eee '= >-ene 'aT alie oor'H --_e a 7s ae a v-c.Home-eeceeeee™oe eae eee.1 aroey-_-ve,' =.a”.ueoe 4 | o:?ct '-_oa : 5 =-_ é i a I I I I [eee-es ---e sorejes----»00-001} [ee e- ------*e0e'ot|CAN INT 4 jee om eS oe ay e000't)'VARS SAIEEES WHERE LES 1 ee eee ¢000'1}r WE POLST WET [e-CO |e0'0se} MD°26106 27154 "AFIOVEG WO SHOILIV TKI Cate ON*1IWLE 2LVIOS!"SBS o°l =£3 SOB ANGEL wagND ZiNWO aluL .*"LHOdKR IVWAN aoeOMS@URSOOD°ML°9L @ ATONE -SMOLLIONOD 2eT:IC20 (S/7C RE CHUGACH ELECTRIC ASSOCIATION,INC.StAnchorage,Alaska et October 17,1992 TO:Bradley Lake O&D Committee aLEE FROM:David W.Burlingame,Manager,Power conesoySUBJECT:HEA Outage -October 16,1992 On October 16,1992 the HEA system experienced a complete outage to its system.The outage was experienced during a scheduled islanded operation from the Anchorage systen. At approximately 06:30 Chugach and Seward began switching to isolate the City of Seward from the Chugach system and island the Kenai.Seward was islanded at 07:13 and switching proceeded to island the Kenai.The Kenai was islanded at 07:54 with Bernice Lake unit 4 and Bradley Lake units 1&2 on-line. It was decided to resynchronize the Kenai and Anchorage systems to allow for testing of the Quartz Creek -Soldotna 69 kV line on the interconnected systen.At 08:01 synchronizing was attempted at Daves Creek and was continually tried up to 08:11.Frequency variations in the Anchorage and Kenai areas prevented synchronizing from occurring. At 08:11 Bradley Lake unit 2 was placed in deflector to help stabilize frequency.Frequency initially decayed to 59.5 after the unit was placed in deflector and then began to rise with the power rise on the Bradley Lake unit.AGC control of Bradley unit 2 was disabled for 45-60 seconds as the unit was ramping up at a high rate.The unit was placed in Base mode to see if the ramp would settle out with a low base point but the ramping continued. At 08:14:22,3:22 after the unit was placed in deflector,frequency reached 65 Hz tripping the all three Kenai generators off-line. Power was restored through Daves Creek Breaker 726 and Bernice Lake synchronized on-line.Bradley was placed on-line after Bernice controlled the voltage to allow synchronization. With the systems tied together,it was attempted to place Bradley unit 1 in the deflector control mode.The mode change failed. Bradley unit 2 was placed in deflector mode and immediately began ramping up at a high rate.The unit was placed back in speed mode at approximately 20 MW and was returned to its base point of 12 MW by SCADA AGC in a smooth transition. Approximately 10 minutes later,the unit was again placed in deflector mode and began ramping up at what appeared to be the same rate as seen previously.SCADA AGC was monitored and it was verified that AGC was attempting to pulse the unit lower during the time it was raising.Frequency was in the 60.1 range.The unit was placed back in the speed mode and immediately went to 2 MW, then tripped off-line on reverse power. Until further testing is done we have disabled our automatic trigger to deflector mode upon islanding detection and will not use the deflector mode option. The use of Bradley Lake in power restoration to the Kenai appears somewhat limited as both times we have needed the units to be synchronized back on-line quickly,we were able to synchronize a gas turbine first.It would appear Bradley should be able to get back on-line first but may have problems synchronizing to the system with unstable voltages. We will be doing some more deflector tests this week to isolate the problem and will keep you advised. "Fes.OCT 16 '92 10:13 BRADLEY POWERHOUSE (9@7)235-S5413 4 2 i.7.th.epeeof.otonereee|xt3.aeasee,2setesigs-beaealngSsdonetateoeMisia Energy Azcootty : _ A,Public Corporation ro S '3TELECOPY|.e 78 (Dezdltey Esti TEdrodlectric Project Teleces Pin:reer¥ae4itge.°eosSheanakeceteeots.eeepTeecrah,re.oogfuapneteto33:: 1. eS .7 erat toe fey taalLatiog?(senfzescises ety une roan es ia |€07)'561-7877 Anthorags Ta)PO.Ron 1886"30%Eitts Tndor Bead Anthedige,Malis $519-tete 'tin sonnet *coat:twht BY J et eRe oes avota'.? eye e,At..ee plltyae wesbegee te Ce |=. ee - eo . of.t t,”2 ad<.).EPORT REQUEST OK ns ageYet¥2 ceo R aR ae Me phe ee Ee"iatsesa"eg &Q *%a.oginn,Se °Mle 'hin 'Me : ,PAGE #08 €0 r - :ry x,figGe.- WMBTER COMMS ==of 1 MASTER COMM3}06 15-OCT 15:53:54 DOWN MASTER COMM 3 2@5 15-OCT 15:54:35 UP MASTER COMM 3 .a""E"Ying a5-0CT 16:@2:29 DOWN | -s-MASTER COMM 3 es cnDens748-OCT 16:02:35 UP oe MASTER-COMM.3--.---Te ne.oO ="B5=0CT "16209339 DOWN->°"MASTER COMM 30.00 fo tre EE,a"$09 15-OCT 16:09:35 UP .MASTER COMM 3 he ae -ar 318 1s-0ct 16:16:09 DOWN MASTER COMM 3 ; Fi 242 15-OCT 16:16:15 UP MASTER COMM 3 1 ¥12 16-OCT QS:11:26 IN...AS-MASTER STA U2 'DEELECT came verte atefi°:323 16-0CT 68:15:RIPP 41- POWERHOUSE 13 LoB-.nyt :ee 2416 16-OCT @8:15284 TRIPPED '[-POWERHOUSE U RLY |j ;Raw,225 16-OCT 98:15:94 TRIP _...L-POWERHOUSE G1 Le.be bs Q*et -weeege oen oe :weN..16 16-OCT @8:15:04 NORMAL 2 1-POWERHOUSE U1 VOLT BALANCE Ar=«917 16-OCT 08:15:06 TRIP 1-POWERHOUSE G2 L.O..ie .218 16-OCT @8:15:6 DETECTED 1-POWERHOUSE G2 UPPER SUMP WTR.Jig 229 16-OCT @3:15:P6 DETECTED ...-1-POWERHOUSEG2G2 Lo en 4 Gin.zTye,«228 16-OCT @B:15:86 DETECTED=1-POWERHOUSE Gi UR Y ot ceBee$21 16-OCT gS:15:06 eTESe "4-POWERHOUSE 64 _L MER sume Witte”=o 922 16-OCT G8:15:08 E *aB-MASTER STA BUS.|27 RY.8 ee aesx22316-OCT 215243 FI 15-MASTER STA F PROT ALARMtH»26 16-OCT 88:15:59 NO 415-MASTER STA FIRE PROT ALARM Re 225 16-OCT @8:15:59 15-MASTER STA BUS -US2 27 RLY a™.ae oe "soe . e .ss !cae tgerate gente!SS:gabegtete Tt .ee YGet-yt6 16-OCT BEAESIB1 "|-POWERHOUSE a ae a ate ateinesad16-OCT 98:16:82::-,1 POWERHOUSE ET ° nee 16-GCT Gh:16:02 1 POWERHOUSE 80 sere de,ae x BF 16 -OCT 6:04 ."15-MASTER STA Fi="930 16-OCT 08:16:05 NORMAL 15-MASTER STA FIRE PROT "ALARM o U2 146.2 HW 1@@ KW 66 KW 59.9 24.4 MW 58 KW Ul 18.1 rid -9 MVAR U2 STA S PRI FAC FREQ -NET OUT >,eRe 'Uk STA 'S,.,she QRYA |he END OF REPORT .7 .3,sot ta ae "he!i.i.wae teeee ne '+: )°, estes "h o 3 ae tabs : ..v8 Bee one "gc nee see asad nab emry)a wvabEiwe..Boe ce a,Pi and a Se -a od. ceqredee esaayceee|WA Te LN rea lis"at es oy .-abot wersy tee Pee -ef. .Be --. a ry r "ny 3 wee = 1 we Cy a .eet ee ye tone oe 4s . 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")j,-.289 -16-OCT 00:02:24 EX HIG _k2-SUBSTATION MESSAGES SENT |eo ote¥16 16-O0CT 88:29:02 EX HI A5-MASTER STA MESSAGES SENT ee 211 16-OCT 96:58:@6 NORMAL '7-LOW BRAD RIVER 45239079 RIVER FLOW3)12 16-OCT 46:34:59 STAR 15-MASTER STAU2 AUXILIARIESU21316-OCT 06:34:59 START 1-POWERHOUSE U2 THR BRG OIL PMPm.914 16-OCT 06:35:00 NON RoE 3-MASTER STA UNIT.-2 NEEOLES wins teed')"915 16-OCT 06:35:0 E IS-MASTER STA U2 MASTR START RLY guyXKabe..Bee a ' °e 'SeayQ"916 16-OCT 96:37:18 STOP ae 1-POWERHOUSE U2 THR BRE OIL.PMP pee we SG Y &.917-16 -OCT86:37:32 ELOSED°d-1-POWERHOUSE U2 LD BRKR a un +18 26-OCT 06:63:28 CLOSED 1 POWERHOUSE G2 BRKR 2GMS-ACB1w)919 16-OCT 88:11:26 DEFLECTOR 1 POWERHOUSE U2 PWR-SPD-DEF MODEQ.22@ 16-OCT 08:11:48 LOW 15-MASTER STA SOLDOTNA LN FREGode.:."wy .:mo tee oar bs +wage wey042116-OCT.98:11:48 LOW d.-"LSMASTER STA DIAM RD@ LN FREQ _aS3)eh 22 16-O8T 8:12:51 PAL (a 2S-MASTER STA SOLOMTINA LN FREQ *Hers oT ey oea *")23 16-OCT 88:11:51|15-MASTER STA DIA vin LN FREQ ...wa datule tt>#e¥2Qh 16-OCT-gerisias PATS HHS-.sei-4545-MASTER SBA DIAM-RDG ON FREQ 9 fe.-8 0)Files Sent ci ates='925 26-OCT 08:13:46 HIGH 15-MASTER STA SOLDOTNA LN FREQ rd -:4 =.226 16-OCT 98:16:11 EX HIGH 15-MASTER STA DIAM RDG LN FREQ(i XR7 16 OCT 08:16212 EX HIGH -18-MASTER STA SOLQDINA LN FREQ x."ej EET OE«2°228 1-OCT @8:14:28 CLOSR®:.2 X-POWERHOUSE UPS”KR aR©).229 16-OCT Q@8:14:29 CLO ."Be -POWERHOUSE UPS a eeat.16-OCT G3:16238 CLOs "{-PoERHOUSE UPS KR Lan cs.ome ;oat ate =oe Soneee oc RA.foyU216.9 My KW”63 KW 59.9 25.7 MW 4&9 DSM WoUL 10.3 tm%) 1.9 MVAR U2 "STA S PRI FAC FREQ NET OUT >RESET ur 85 AS -1.6MVA4<5 END OF REPORT ae *.an - 4 a oh x .:oe eae +397.ts at reyb)'é A ;,e)ee a Le :.1;Py ,ial =ofp 'ren Be msreerPeaeserSeatD7 ge:-gow.7acaa"att ry14ehtre .ea a oS Sa o he at we .tc WES e Ryde TE ape are Et ae thier co 8 -ype! ys re ae sad y eres ta "Bre, are ceewrme -_ots ano,.Tae "ere o 5+..ae ca :wool LY Oc os Fak * we HeteedcenA,AIRESUO.tite mers 2G te 2S ways wes:Hitt Fn wae'ie te ; n . a voce rh oe "a .ae '-geey..ie-gct-"h¥a.ce:3:34CRT IMAGE DISPLAYED AT CONSOLE 2 3 >cae .%,aes >aw .ay i re .,ana ot aie =ee a ere 1 vr -- sf Dianne a r Sata .*He mos 'ren .we pligea?.aye <oy %$9 ar :elt 2 *a -v a Td.-st oe rF 4 .°*ee,:.'esis..OE a Ba Seem BPE:#¢aA SSS.®"7 7 ame NOWGREFICAL ALARM 'SUMHARY'- ns peeps EY uw se,DATE.__TIME |STATE..M_.STATIQN NAME /DEVICENAME 2 |owes_We _a wale S,282 46-OCT 08:14:31 CLOSED 2 1-POWERHOUSE UPS BRKR>@2 16-OCT 48:14:32 CLOSED 2 1-POWERHOUSE UPS BRKR>@3 16-OCT @8:14:33 CLOSED 2 1-POWERHOUSE UPS /BRKR@416-OCT 08:14:34 OPEN 3 1-POWERHOUSE UPS.BRKR»)2@3 16-OCT @8:14:35 CLOSED 3 12-POWERHOUSE UPS BRKR -OCT 98:14:36 CLOSED 2 _1-POWERHOUSE UPS congener gies eee denbhgen |wee ee egeeeeets_her',OT @8:1K:37 BEOSED "*"27 I=PORERHOUSE UPS,Ro homes :ae ig he ee eeVwAG-OCT 8:14:38 'HIGH 42.18-MASTER STA Uz.Paste ee .a we an 6-OCT 08:14:38 CLOSED es PTEQWERHOUSE,RKR ;ae ca :abb)RAD O-OET 08516239 CLOSED_"POWERHOUSE Ut Sake EA Se.942 16-OCT 08:14:40 HIGH 15-HASTER STA U2 AMPS PHASE C +>:Yi2 16-OCT 08:14:40 CLOSED 2 1-POWERHOUSE UPS BRKR 0 213 16-OCT 08:14:£1 CLOSED 2 1-POWERHOUSE UPS BRKR _wotis,*MTS S-OcT Garis 42 CLOSED '---2--t=POWERHOUSE UPS BRKR "O45 ;oeDyngass:T Q8:16:43 CLOSED 2.JAPOWERHOUSE UPS BRKR-«00,i er oS a z °.'""ne ook one 2 feed..OF ee»AgedAG-OCT 08:14:44 CLOSED * 2:&-POWERHOUSE UPS BRKR"7"*a ' =16-OCT 08:14:45 NORMAL ”15-MASTER STA U2 AMPS P B meS. -18 16-OCT68:14:45 NORMAL 15-MASTER STA U2 AMPS PH CcO.19 16-OCT 08:14:45 CLOSED 2 -1-POWERHOUSE UPS BRKRY2@.16-OCT @8:16:45 NORMAL.2 A-POWERHOUSE U1 GOV ELECTRONICS peers cocaWGbeerens-riee sonst warr S a Tare ca pil>:2:14:46 CLOSED |POWERHOUSE UPS.BRKR.nate ane ger Tagline pes cdxOB:4:46 gk Low 2 xbe "MASTER BTA u1 WATTS :Ae ree .np.can :os *ghee "6 s 5 98:14248 .CLOS "2 3 ERHODSE 'SsBRR °F "ps Se,gti ak nee oe 4 GB:14:48 CLOSED T"POWERHOUSE UPS BRKR =<Te oe.3 @8:14:48 LOW 15-MASTER STA U1 M WATTS by CT 8214249CLcLoskp 2.[J -POWERHOUSE ues BRKR a a ee a a,j eee 2 cLoseD Hj Areoerouse IPS ABRKR a hj One poe af HYaWET28316151CLOSED=F.ASPONERHOUSE RAE ve Boa . .m8 a,AGUOET @B316552 CLOSED «4 ukePOWERHOUSE UPSBRKR *srette:0![|o#. se «(U2 16.9 Mw 48 KW 63.KU 59.9 25.7 MW 69 DSM 58 KW U1 19.4 °MWa9MVARU2STASPRIFACFREQNETOUT)RESET U1 STA S =6MVAa bd a ge OF REPORT *e Lg €st.rs awexeMe:ath a,hes :Swe Wee wtDorrdsie.oe °-"teons ig aes re aem.-"ame ae ioe koa aeabeaeSkalRil4aryaisLf'ee reece + Oo : ce)a eee oe heb gore woe meine Rie =.vee e cesta )Seg 'z "Hy .NRA ty enesi rth cpg 8 a hs _s °.oo Me . 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QR..- Snes .A ty oi?Re te EN at se POS.,{ine eA)iearil Oo yemete geaifiterrs .io .weer wees =""4 o ..+..1 ca wey:someds3.Whe da "eeBets «ry io Ps oe wy 'hes ogee a is °o Fae,il we .noes rs 5 ow ede.Te ae wietah tte.«Kae2 PRT anaes QEEPLAVED a.CONSOLE 2 Wee fe ionsitipie Tereges Sie? bee De On ae.ner SL)te a oh:&S '<del "5 Eo : OB ape HEH eth Bet ee reiceneae eeig de ORS «2 OS-Yat*avL,vie surfian rey kaos 2,Foesepeeia:Be Nan pede oe ---®DATE._..TIME...STAJE...M...STATION NAME /.DEVICE NAME,; ):¢°.3B2 26-OCT 98:15:06 EX LOW 45-MASTER STA DIAM RDG LN FREQ!:"**¥@2 26-OCT 88:15:06 FAULT |.1-PORERHOU U2 GOV ELECTRON>@3 16-OCT 98715206 FAULT --4”POWERHOUSE U1 6OV ELECTRON i ain Tl elt sine anle °ee ty :.os ant Ton ey tg i .2@%16-OCT 08:15:06 COI bee TE ves es fcc ne pie ..)2@5 16-OCT 08:15:08 TRIPPED »35-MASTER STA UNIT 1 NEEDLES «A5-MASTER STA BUS US1 27 RLY : 3 ftpty >i reeR STA -ERIFAC ACB IOMER*et"MASTER STAY, --£5-MASTER-STA-US2--SUP--ACB2G1-:1-POWERHOUSE U2 M XFMR CONT PUR Eesletiovs DIESEL GENERATOR .a :o¢3!4gPOWERHOUSEE COMP:CLG.PUMP PQA ke Sede |raceate ir:62067.115:15%ae a Fs .,or eS Col.sh a "+b.ta:.".-POWERHOUSE "02 GOV ELECTRONI roy2sioe2:15:15NNORMAL 1-POWERHOUSE U1 GOV ELECTRONI er tem nme tee oP tN eat31816-0ct 08:15:16 NORMAL 2 15-MASTER STA AHU1 FLTR DIFF PRES1916-OCT 08:15:16 NORMAL 2 15-MASTER STA AHUS FUTR DIFF PRIS - wry 16-OCT g8:15:326 NORMAL,_2 15-MASTER STA AHUS FLIR DIFF PRESrirerena8:a5:nat :ad DASTER'STA.,TR DIFF i ds 3°;rhe RT coc tena pedey esPiet abe=OCF B83 7 G BAS eR.ON eroS RSE Re[awed 6-0CT..spit?|:ih.ee STAibr Apein VOLTS:es MPH PN ER apes22%16-OCT*aM BREE ae RE TRE Geta atime 9b ysLHeerahfeteeiemetege4tgaeyao 'Se°(o)=B8iaue' oie>aotSE(987)235-5413raeolS15317'pe-")25 16-O0CT 2:15:17 NORMAL derhasien STA U2 cy VARSaleSenocrwate:aa.FAIL RE -s_-s.1 -PQWERHOU IE SEN CON Svar wt :Y : 4 :ty .:7,ts,Lana :.meKW63KW'$9.9 25.7 rvs "49 DSM 58 KW Ua 19.qn -.-1.9 MVAR U2 "SrA S.PRI FAC EREO NET OUT 2 RESET U1 GTA S++.-1.GRVA : Set . .ak END OF RERORT o>ea es ee fe ee eee ome ar a*.'q ° .age "ee'Buea .>gia:i ar a aEoe.'.es c Geer i eadin 7 Vokes og Si tte,the . .q uy me:Sr See eee”©,e. we a "t :..* oo we es '=wOCT16'S218:28BRADLEY-COWERHOUrhs y ; =60 .we iss oe ¢vot ins aa Oe a ote "ar nmPera rd *ae:eros.ey Tae ae. 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OBS I3ia8 08313'48 08314300 08514302 08514302 08514321 O8st4i2 OBI 14522 08514523 OBI 14324 08314325 OB8F14825 08314325 08314528 08814532 O8f14332 OBs14334 08524335 08514536 OBF14i36 08514837 08514338 08514538 08314340 08514340 08534341 08314541 08514341 ob814841 08314341 9Bit4i4i O8s14t4l 08314342 08514342 08314342 08514342 08514342 08514342 08514342 OBF14342 08514342 08514342 OB314542 OBS 14342 08314542 OB8814i43 0814343 08314243 Oast4s44 OBt 14344 98314344 08314344 08314544 08314344 08314345 O8F 14545 O8F14545 0824845 06314345 VERNILE BRAK wc AVA Ciece |ieee eee QUARTZ C SOLDOTNA LINE FREQ HIALH 2 61.02 LH 61. QUARTZ C BRKR 426 UNCOMMAND STATE TRIPPED COOFER L 69 KV LINE LOALM 1 0.84 LM 58.6 COOFER L UNIT 1 EXC AMFS LOALM 1 -110.0 LH =-3.0 COOPER L UNIT 2 EXC AMPS LOALH 1-99.05 LM -2.0 BRADLEY HC FOWER TRAL STATUS NOW ALARM BRADLEY DNC POWER TRAEL STATUS NOW NORHAL RRADLEY NC POWER TREL STATUS NOW ALARH COOFER L ANY ANNUNCIATOR STATUS NOW ALARM CQOFER L EMER GEN ON STATUS NOW ON BRADLEY Ui TREL STATUS NOW ALARM BRADLEY Ul TRL STATUS NOW NORHAL SOLTOTNA 115KY §RUS KY HIALH 1.139.63 LM 119.0 FERNICE UNIT 4 MW LOALM 1 -3.14 1M -3.0 BRERNICE BRKR 526 HW LOALM 1-13.88 LH -10.0 REFNICE BRKR 526 HVAR HIRST 1 6.26 LH 41.0 SOLTOTNA 115KYV S BUS KY HIKST 1218.26 LH 119.0 RERNICE BRKR 426 STATUS NOW TRIFFED RERNICE UNIT 4 CALL NOW STATUS NOW ALARM BRADLEY 2 HOME CHANGED TO BASE PERNIFE LAKE 4 CONTROL SUSFENDEN BRADLEY Utd TREL STATUS NOW ALAR BRAGLEY Ui TREL STATUS NOW NORMAL RERNICE UNIT 4 HU LORST §-0-02 LH 8 -2.0 RERNICE 4KY BUS VOLTS LOALM 1 3.77 LK 3.9 BERNICE 69 KV RUS FHI LOALH 1 62.48 Li 65.5 BERNICE XFHR TROURLE STATUS NOW ALARK RERNICE UNIT 3 CALL NOW STATUS NOW ALAKH QUARTZ C BAT CHARGER DC TREL STATUS NOU ALARM QUARTZ €BAT CHARGER [iC TRAL STATUS NOW NORHAL QUARTZ C BAT CHARGER DC TRBL STATUS NOW ALARM QUARTZ C RAT CHARGER AC FAIL STATUS NOW sLARM QUARTZ C RAT CHARGER AC FAIL STATUS NOW NORHAL QUARTZ C BAT CHARGER AC FAIL STATUS NOW ALARK QUARTZ C 426 OVERFRA RELAY HALF STATUS NOW ALARH DAVES CR QRTZ L1SKV DE-EN STATUS NOW ALARM OIA RIDG BAT CHARGER AC FAIL STATUS NOW AL ARH SOLTOTNA OCR AC/NC LOSS STATUS NOW ALAR SOLBOTNA BRKR RELAY FAIL STATUS NOW ALAKH SOLROTNA LOSS OF MTR FOT STATUS NOW ALARM SOLTOTNA UNIT!READY TQ STARE STATUS NOW NG SOLNOTNA UNIT!READY TQ START STATUS NOW yes SOLTOTNA UNIT 1 ALARM PRI 2 STATUS NOW ALARM SOLEOTNA STN BAT/AC TRL STATUS NOW ALARM SOLDOTNA BLFF 115KY HTK NO AC STATUS NOW ALARH SOLNOTNA DIMND RIDG MTR NO AC STATUS NOW ALAR SOLUGTNA QRTZ 115KV MTR NO AC STATUS NOW ALARM SOLDOTNA BRADLY LAK MTR NO AC STATUS NOW ALARM SOLDOTNA GEN1 METER NO AC STATUS NOW ALARH SOLDOTNA QRTZ 69KV HTR NO AC STATUS NOW ALARH BRADLEY U1 GEN BRKR*.STATUS NOW TRIPPEDRRADLEYU1GENBRKRSSTATUSNOWCLOSET BRADLEY Ui GEN ERKR STATUS NOW TRIPFEO BRADLEY U1 666 LOCKOUT STATUS NOW LOCKOUT BRADLEY U2 GEN BRK STATUS NOW TRIPFER BRADLEY U2 GEN BRKR ;STATUS NOW CLOSER BRADLEY U2 GEN RRKK STATUS NOW TRIFFED RRADLEY U2 666 LOCKOUT STATUS NOW LOCKOUT BRADLEY U1 MAIN XFHR TREL STATUS NOW ALARM RRATLEY Ui MAIN XFMR TREL STATUS NOW NORMAL FRADLEY US HAIN XFMR TRAL STATUS NOW ALARM RRAILEY Ul TRIP STATUS NOW yes .aleoloeoooleleenoelneeiaeenioeiee10/16/92 10/16/92 10/14/92 10/18/92 10/16/92 19/16/92 10/16/92 10/16/92 10/46/92 1G/16/99KYATIL) 19716499IGEbes99 19/1492 10/16/92 10/16/92 10/16/92 19/16/92 19/16/92 10/14/92 10/16/92 19/16/92 10/14/92 15/14/92 10/16/92 19714792 10/16/92 10/15/92 19/16/92 19/16/92 10/16/92 19/14/92 10/16/92 19/16/92 10/1E/92 10/46/92 19/16/92 19714792 14/16/92 19718792 10/46/92 19716792 10/16/92 19/16/92 10/16/92 10/14/92 19/16/92 19/16/99 10716792 10/14/92 10/48/92 19e1h92 10716792YatSL 19746792 LOCE 98 19/98/92 1/14/92 19/46/92 1916592 1Ocp4 G2 Verge 9) oe 600 om i Ueoe 08314546 OBS14546 OBS 143446OB514346 OBS14546 0B514346 08514346 OB14546 OBT14344 Ons t447 OBS14247 98514347 ORS 14547 9Bi14548 OBl14549 O8s14549 OR8T1449 9814549 OBI14549 OBS EALAG OBS 14s4g OBI14249 08314350 08314559 OBtt4i5e OBT14IS9 O83 84250 OBbASo OB8S14550 OBEt4I59 08514350 98814559 08314350 OB T4tlO oa8s14iso OB314550 0B214350 oBit4aisl OBi14ist OBI14851 OBS14551 OBs 14851 OBS 14S! OBT14551 08315308 On 1S!08 O88 15308 OBS 15508 08315508 98315508 O83 15568 98515398 ORS IS08 OBS 15308 OBS1SS68HBIt5298 08315508 OB 15208 OBF15868 perteses Ont og Ameamaan RRADLEY BRADLEY RRADLEY RRADLEY RRAINEY BRADLEY FRATILEY BEAPLEY BRADLEY READIES PRANLEY READIES FRAIL E? RRAPLE?2 SOLTOTNA SUL DOTNA SOL HOTNA SOLUOTHA SOL OTNA Sa hOTHA SOL OTNA SOLTIOTHA QUARTZ C NUARTZ C QUARTZ C MART?C ANART?Z ¢ QUARTZ € tilA FING CIA RILG [NIA RIDG P1A FIG UTA RIG iA KITG tik RIOG WA RITG DIA RILG REENICE RERNICE RERNICE REFNICE REENICE FERNICE RERNICE RERNICE BERNICE BERNICE BERNICE BERNICE RERNICE BERNICE BERNICE RERMICE REENICE BERNICE BERMECE RERMICE HERMICE RERNICE RERNIFE BERNICE RKERNTICE meewene HAIN KF TRBLU2 STATUS U2 MAIN XFAUR TRAL STATUS U2 TRIF =STATUS U2 TRBL STATUS U2 TREL STATUS U2 TRAL STATUS 115 KV LOSS OF NC STATUS 115 KY LOSS OF OC STATUS 118 KY LOSS OF I STATUS §.S.4B0V EAR TRIF Stars €.8.4804 BRR IKIF STATUS S.S.469)BRE TEIF STATUS S.S.13.2 PRR TRIF sraric CONTROL SUSHENTEL JISEU N RUS KY (QALH ft TiSheV WM BUS HZ HIKST 1 115k N RUS HZ LOALM 1t LiSkY S BUS AY LOALK 1 1I5Ku S RUS H7 HIEST J P1EKY S HIS HZ LOALM I UNIT 2 HZ HIEST 1 UNIT 9 H2 Ue | 118 kY RUS LQ4ALM 1 69 RV RUS tate 1 ANCH LINE FREQ HIRST 1 GNCH LINF FREQ LOALM ft SOLPOATNA TINE FREQ HURST 1 SOL|@OINA LINE FREQ (Qaim ft 115 BUS KY FH A UT ae | 115 BUS KV FH RB LOGLM 1 115 BUS KY FHC {OALH SD 69 RUS KV FH A (OALM ft 69 BUS KY FHA COeLH 2 69 BUS KV FH &LOALH 1 69 BUS KY FH E Lane 2 69 BUS KV FHC tQalM ft 69 RUS KY FH LOALM 2 HEAR 526 MW LOKST 1 4KY BUS FREA HIEST J 4k)BUS FREQ {OAM 4 69KY BUS FREQ HIEST 4 49KY BUS FREQ LQALM 1 UNIT 2 CALL 2 HRS STATUS UNIT 3 CALL 2 HRS STATUS RRKK AIR FRESS STATUS UNIT 2 CALL NOW STATUS UNIT 2 CALL NAW STATUS UNIT 2 CALL NOW STATUS UNIT 2 CALL 24 HRS STATUS UNET 2 CALL 24 HES STATUS UNIT 2 CALL 24 HRS STATUS UNIT 2 FIRES!STarus UNIU 2 FIREt!STATUS UNDE 2 FIREES STATUS UNET 2 WYO RCHT TFPI STATUS HET 2 Het RCHT TRE STATUS UNIT 2 HYD ECHT TREL STaAtus UNIT 4 CALL 2 HES STATUS WATE 2 TURE ATF TMLE StAtUs HERE 4TR FRESS STATUS RRRE ATF FRESS STATUS RERR ATE PRESS SbATUS re a,oe Oe Pe Cn eet Now NOW Now Now NOW NOW NOW Now NOW NOW NOW NOW now A.76 49.71 49.71 R245 49.aa 49,44 50,72 $0.72 0.00 0.90 55.00 53.09 $5.06 55.99 2.59 4,99ete 2.43 4 0.27 0.27 9.36 0.34 G.2? G.07 -0.01 55.049 55.90 0.00 55.09 NOW NOW Now NOW NOW NOW nau How NOU NOW Now Nau HOW NOW Haw NOW NOW Now NNW NOW armies NORMAL ALARM YES AL ARN NORMAL ALARM AL ARH NORMAL ALARA TRIFF ET CLOSEr TRIFFER TRIFFER 119.3 é0.1 §9,¢ 111.4 0.) 59,¢ 0.1 59.6 111.0 64.5 4g. 99.9 Ativan 53.49 1.8 117.4 119.9 4o,4 é0.0 62.3 44.6 $2.3 €0,9 "19.0 40.4 59.4 é0.1 Se.4 LM U4 4 tM 'T,) th ALARM NORHAL AL ARK ALARN NORMAL ALARM ALARM NORMAL AL ARH Al ARH NORMAL OL GR AL ARK ALARM NORMAL Low NORMAN arr Maal .SeteeeteteeteeteteeteteeeeeeeweweCeieonoewe we we10/16/92 10/16/92 10/16/92 19/16/92 10/16/92 19/16/92 10/16/92 19/16/92 10/16/92 1orbgsey 10714792 1Hrtssep $O-9£°99 Tartare 10/18/92 19714792 10/16/92 14/24/72 19/16/92 10/14/92 19/14/92 19/18/9210/16/920 10/16/92 1016792 19st son 19/16/92 19718792 10/16/92 19/14/92 10/16/92 1LO/t4292 19/16/92 1o/16/99 19/16/92 19/16/92 10/16/92 10/16/92 10/16/92 19/16/92 10/16/92 16/16/92 10/16/92 19/16/92 10/16/92 19/16/92 10/16/92 19/16/92 10/16/92 1/14/92 1914/92 1a pseya 10/18/99 lesnesen 10/1692 19/14 I92 1946799 Wart gs92 14ye762 barqeee 19-46509 1614992 vere 06 ) 0B ) 08,) OBS 15040 08315510 08315310 0815510 08315820 OBS 15332 OBS18s36OBSESEISGBIL37 OBSTET OOsisia? OBIIS237 OOit5638 985152338 OBS £348 08315838 OBE15338 oer ieeagoa1STeOgi15OB1st4d O8ltss4d 08115240 ORF1SI41 oB8isi4l GBIISs41 OBI ESI 4d OB 142 OBI15342 08315542 08315342 OBF15t4g OBS1SI43 OB815843 OBE1S343 OBF1SI43 OBIS AZ OB515343 OB8F1ST45 OBF1S546 OBS1S146 O8Ft5247 OBs15847 OBF15349 OBS 1S 4ag OBS 1SIS0 ORT1SI50 OAS at$50ORLISS"0 ORPIS999 LO SiH OBSISiSt ORS LES NOUETISE oerisesy OBITS OBIS ERB Bae | br PEOUR RERNICE RERNICE RERNICE RKERNICE BERNICE RERNICE RERNICE BRADLEY (AVES CF REATILE? FI HACKE FT MACKE PAVES CK VAVES Ch PRATLEY QUARTZ € RERNICE SOLTOTHA SOLTQTNA SOLUOTNA FRAWLEY BRADLEY RRADLE' THTRNATE INTENATI QUART?C PIA KITG Leet 9 FIND CALL 24 HRS CALL 24 HRS FIRFG HY RCHT TEBL HY!RCHT TREL HYt RCHT TREL TURR AIR INLE UTE UNIT UNIT UNIT UNIT UNIT UNIT UNIT FIRE! BRKR 276 U2 GFN BRKE KEC.EVENT TRIG REC.EVENT TRIG FERKE 774 QRT7 LESRY NE-FN MES AY Gass OF fe 424 QUERFRQ RELAY HALF UNTT 2 Cath Nau OCR AC7iC Lass STN RAT/AC TERI GENI METER HO AE FIRE! 480 BRN TRE 489)GENT TEAL 34,5h"KUS FREA YARLY BUS H?7 BAT CHARGER AC FALL FAT CHORGEF AC FallROPDPSPD8PDoP.ALE EXCESSIVE FREQUENCY FANIC 46C é MILE E RELNGA 8 COOFEF t ENTHTAN SALUQTNA SOLLOTHA SOL LOTNA SALTQTNA SQL TOTNA SOLDOTNA SOLTMTNA SOLDQTNA RERNICE AKL EP AML SF BRADLEY FRATLEY SQLDOTNA SOL LOTNA UNIVERSI UNIVERSE WAVES CK DAVES Ch WAVES CE CAVES CRo1 QUARTZ € QUARTZ € QUARTZ © DIA RIEG (th REDE GIA RING bla RTOG DEVIATION EXCESSIVE CONTROL TN FROGRESS:aCe STATION COMMUNICATION FAILIRE STATION COMMUNICATION FOTLIEE STATION COMMUNICATION FALL URE STATION COMMUNICATION §ATLURE LOS OF HTK FQ! UNIT t ALARM FRI 2 FLFF UiSkV ATE NO AC DIMNO RING MTR NO AC QRTZ LISKY ATR NO AC BRADLY LAR MTR NO AC QRIZ 69KY MTR HI AC BREE RELAY FALL 4KY RUS FREQ MC REN LINE C BV TRANE FH A KY FIRE! FIRE!. TISKY N BUS KY fiSkY S RUS KY 138 KV US FREQ Td C1SKY LY FREQ 115 8US VOLT FHI 115 BUS VOLT FH? 115 BUS VOLT HA 1S RUS FRED 115 KY pus 69 RY RUS BAT CHARGER ttt 115%RUS KY FHA 115 BUS KV FH OR Lis RUS KRY FHF 69 BUS KV FHA TERI DuATUD NOW vee eet STATUS NOW ALARH STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW ALARH STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW ALARM CHG VALUE TO CLOSE ALARA ACKNOWL ERGET STATUS NOU ALARM STATUS HOW NORMAL CLOASFE Vpe SCAlh STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW ALAFH STATUS NOW HORMAL STATUS NOW NORMAL SIATUS NOW NORMAL. STATUS NOW NOFHAI STATIS NOW AL AFH STATUS NOW HOREAI (MALH t $9.67 UM oF. Lath t S¢.4°LH £O,. Stats wow HORMEL STATUS NOW NORMA "40.3 KW "0.504 HH? 40.3 HU COE Véel COLE 144] (ve VAél COLE 14641 STATUS NOW NORMAL STATUS NOW NNEMAL STATUS NOW NORMA STATUS NOW NORMAL STATUS NOW HOEMA STATUS NOW HORMAL STATUS NOW NORMAL STATUS NOW NORMAL. LORST 1°59.54 04 9,4 (GALM 1 224.50 CH 225.0 LOALM 1 225.88 LH 724,48 STATUS NOW ALARK STATUS NOW NORMAL LORST 1 416.66 LM 112.4 LORST 1 9126.59 LH 119.4 LOALK 1)59.87 LM 9,8 LQ¢tM 9 59.44 LH so,? HURST 2 416.43 tH 199.5 HEFST Po dt?QR UM 120.5 HIRST toy'.SO CM MOT. {NGLM 2 SS,6A CH £9. IQSST §117.39 UM 181.4 LORSE 1 74,38 1M £48 STATUS NOW HORMAI HORST PUES.LM ta. PQEST DP Leet tM thee IORST 1 197.06 EH Tts.A LORST 1 65.53 04 Ar.% Seinatinatinadieoeikeoiiaeee)ieateoteikealGinetteenaoeaed>"+In tore 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 19/16/92 10/14/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 1016/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 10/16/92 10/16/92 10/46/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10716792 10/16/92 197186/92 10/16/92 10/16/92 10/16/92 10/16/92 10716792 10/14/92 10/16792 19/16/92 10/16/92 O8t15553 08315353 08815555 O8F15556 08515356 08215:56 O8515356 OBS15357 08315357 08815559 08316303 O8F 16504 08316305 08316505 08116505 08516316 08316322 08216526 08516337 OBI 16539 08516343 08216343. 08316543 08316343 08316349 08316353 08316353 08517205 08817309 OBS17510 08817210 OBS17312 0817313 OB517314 OB317317 08317330 08317333 08317345 08317347 08317349 08317349 08317352 OB317855 08317357 OB1B302 08318317 08518523 OB31B329 08518336 08516543 08318555 OBS 18359 08219304 OBF19304 08219306 08! o8t 08! Hi hile OF BUD AY PDL RUE bo Geen.at wee TIA RIDG 69 BUS KV PH C LORST 2 66.50 LM 60.0 RERNICE 49KY RUS FREQ LORST 1 59,70 LM 59.6 RERNICE 4KV BUS VOLTS LORST 4 864,95 LM 3.9 BERNICE 69 KV BUS PHI LORST t 646.53 LM 65.5 AML SF TRANS FH A KV LORST 1 227.25 LH 226.0 BRADLEY UNIT 2 START CHG VALUE TO START SOLDOTNA 115KV S BUS KY HIALM 1 219.02 LH 119.0 BRADLEY U2 86G LOCKOUT STATUS NOW NORMAL BRAMLEY U2 TRIF STATUS NOU NO INTRNATI 34.5KY RUS FREQ LORST 1 59.82 LH $9.7 INTRNATI 136KY BUS HZ LORST 1 99,87 LM 59,7 UNIVERSI T1 115KV LN FREQ LORST 1 59.81 LH 59.7 QUARTZ C ANCH LINE FREQ LORST 1 59,82 LH 59.8 BELUGA S STATION COMMUNICATION RESTORED COOFER &STATION COMMUNICATION RESTORED COOPER L EMER GEN ON STATUS NOW OFF GAVES CK 115 BUS FREQ LORST 3 59,89 LH 59. BRADLEY UNIT £START CHG VALUE 10 START INDIAN «STATION COMMUNICATION RESTORED QUARTZ €ANCH LINE FREQ LOALM 1 59.80 LM 59.8 COOPER L EMER GEN ON STATUS NOW ON QUARTZ C ANCH LINE FREQ LORST 1 59.63 LM 59,8 6 HILE E STATION COMMUNICATION RESTORED BRALLEY U1 GEN BREE ALARM ACKNOWLEDGE RERNICE UNIT 4 CALL 2 HRS STATUS NOW NORMAL FERNICE UNIT 4 CALL 2 HRS STATUS NOW ALARM RERNICE UNIT 4 CALL 2 HRS STATUS NOW NORMAL RERNICE UNIT 4 CALL 24 HRS STATUS NOW NORMAL RERNICE UNIT 4 SUF/LOC STATUS NOW tac FREQUENCY DEVIATION NORMAL FANIC AGC CONTROL OFF»ACE =-7.00 MW UNIVERSI 138 KV BUS FREQ LORST 1 59.92 LH 5°.8 ACE NORMAL BRADLEY U1 646G LOCKOUT STATUS NOW NORMAL BRAMLEY U1 TRIF STATUS NOW NO UNIVERSI 138 KY RUS FREQ ALARM ACKNOWLEDGED ACE EXCESSIVE -6.4 MW BRADLEY Ui TRIP ALARM ACKNOWLENGEN ACE EXCESSIVE -7,00 KW RERNICE UNIT 4 CALL 2 HRS ALARM ACKNOWLENGED ACE NORMAL ACE EXCESSIVE "6.2 MW SOLTOTNA 115KV S BUS KY HIRST 1 118.26 LM 119.0 RERNICE UNIT 4 CALL 24 HRS STATUS NOW ALARM ACE NORMAL. SOLDOTNA L15KV S RUS KV ALARM ACKNOWLENGEND RERNICE 69 KV BUS PHI'LOALM 1 65.34 LM 65.5 ACE EXCESSIVE -6.01 MW ACE NORMAL BRADLEY Ut 846 LOCKOUT ALARM ACKNOWLEDGED 6 MILE E STATION COMMUNICATION ALARM ACKNOWLEDGEN QUARTZ C ANCH LINE FREQ ALARM ACKNOWLEDGED INDIAN STATION COMMUNICATION ALARM ACKNOWLEDGED HAVES CR 115 BUS FREQ ALARM ACKNOWLEDGED DIA RIDG 115 BUS KV FH A LOALM 1 121.88 LM 112.0 QUARTZ C BRKR 426 ALARM ACKNOWLERGED BRADLEY U2 86GB LOCKOUT STATUS NOW LOCKOUT BRADLEY U2 TRIP STATUS NOW YES QUARTZ C BRKR 426 CHG VALUE TO CLOSE RERNICE 4KV BUS VOLTS LOALH 1 3.89 LM 3. QUARTZ €BRKR 426 CUOSEL VIA SCADA COOPER tL 69 KY LINE LORST 1 66.44 LM 58. +to>errrer+SaaleolenanonlnoloeononMneneeolMUsLEsYZ 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/36/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10716/92 10/16/92 107146792 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 10/16/92 10/16/92 19744799 5 b 08 , } OBF29823 OBF19323 08519325 08819825 OBS19825 OBS19327 OB819827 08519328 OB8F19528 08519331 08219332 OBF19335 OB519536 OBt19236 08319338 08319340 083197340 0B319340 08319240 08519341 08519243 OB819347 OBF19355 08319358 08320307 08320310 08320310 08320210 08320310 08220310 08220310 OBr20%12 08820815 08320318 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STATUS NOW ALARM STATUS NOW NORMAL STATUS NOW NORMAL STATUS NOW CLOSED ALARM ACKNOWLEDGED ALARM ACKNOULEDGER ALARH ACKNOWLEDGED CHG VALUE 10 CLOSE ALARM ACKNOWLENGER CLOSEN VIA SCALA ALARM ACKNOWLEDGEN ALARM ACKNOWLEDGED ALARM ACKNOWLEDGED ALARM ACKNOWLEDGER ALARM ACKNOWLERGER LORST 1 226.64 tH 2 LOALH 1)19.63 LH LOALM 1 -264.7 LH 8B LOALN 1 -125.0 LH 2 HIRST 1 60.03 LH STATUS NOW ALARM STATUS NOW NORHAL HIRST 1 60,02 LA HIRST 1 60.02 LM LORST 1 65,91 LH 60.1 60.1 65.8 LORST 1 66.63 LH 20.0 LORST 1 869.28 LM 800.0 LORST 1 347.02 LM 278.0 ALARM ACKNOWLEIGED HIALM 10 26.212 LH 26.2 ALARM ACKNOWLEDGED ALARM ACKNOWLELIGED ALARM ACKNOWLEDGED ALARM ACKNOULELGED HIRST 10 26,03 LM 26.2 ALARM ACKNOWLERGER ALARM ACKNOWLEDGED ALARM ACKNOWLEDGED (LARK ACKNOWLEDGED LOALH 1 -3.67 tH |20.0 LOALM 1 -264,.0 LM B00.¢ LOALH ft -219.2 LH 278.¢ OTATIVO nimit os AOU ieeeeeee10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/16/92 10/14/92 19714792 10716792 19/14792 19716792 10/14/92 10714792 §9/16/92 19/16/92 10/16/92 #19/16/92 eeee+eosetete10/16/92 10/16/92 10/16/92 16714792 10/16/92 t0/16792 10/16/92 10/16/92 10/16/92 10/14/92 10/16/92 10/18/92 10/16/92 10/16/92 10/18/92 19/16/92 10/18/92 19/18/92 10/16/92 10/16/92 10/16/92 19/16/92 10/14/92 10/14/92 10716792 10/16/92 10/14/92 10/16792 10/16/92 10714792 10714792 19/16/92 10/16/92 104146792 10/16/92 10/14/92 10/14/92 lO4Ih792 1o/h/en 19/16/92 19/14/92 99/16/92 1O/16592 08i 0B! 08%. 0Bt5a.<6 08353358 OB8S4314 08354519 08354347 OB:55:01 OB56i58 08556359 OB3546359 OBIS6sS OBISBt4B 09390528 99590132 O9293i21 09394320 09304322 09504524 S90437 69304342 09205:24 09205225 09395143 09305343 09805146 09506130 99306333 09307847 09812354 09813300 O9883s31 OFsi3t4s 09313553 09516300 07516302 O9stesi4 09317333 OFF17240 09318518 098290839 OFF 29349 O9s24ail?7 tOPOONSINDDDaete&@POS09334256 OFF 3456 O9STAtSS ACE NORMAL RELUGA G UNIT 3 GAS FLOW RELUGA G UNIT 5 GAS FLOW UNIVERST 136 KV BUS FREQ UNIVERSI 138 KY BUS FREQ BRADLEY U1 TRRL BRADLEY KLATT ALATT RLATT KLATE KLATY ALATT BRALILE' KLATT KLATT SOLTOTNA SOL EMTNA SOLDOTHA SOLGOTNA SOLLQTNA SOLDOTNA SOLTOTHA SOLTIDTNA SOLTOTNA SOLDOTHA SOLTOTNA SOLDOTNA SOLFQTNA SOLTIOTNA GIRKWOOD GIENWOOE FT MACKE FT MACKE FIELD OT GIRDWOON GIREWOOR SOLDOTNA SOLDOTNA SOLTOTNA U1 START SEQ FAIL RLDG INTRUSION BLDG INTRUSION FER 212 SUP/LOC BKK 282 RCLO BRR 212 RELO BKK 212 RCLO Ul GEN BRAK BLDG INTRUSION RLDG INTRUSION UNITI READE TO START UL START/STOF UNITE READY TO START UNIT 2 ALARH FRE 4 NTT 2 ALARH FRI 4 UNITE READY TO START UNITE REANY TO START UNIT 1 ALARM FRE 4 UNIT 1 SUF/LOC UNITI READY TO START UNIT 1 SUF/LOC UNIT 1 SUF/LOC UNIT'READY TO START UNIT COMBUST FLAME BLING INTRUSION BLOG INTRUSION STN INTRUSION STN INTRUSION LARRY/KEVIN BLOG INTRUSION BLUG INTRUSION UNIT 4 ALARM FRI 2 U1 START/STOF U1 GEN BKR SOLINOTNA 1 GIROWOOD BLING GIRDNCOD ALOG SOLDOTNA UNIT 1 SOLMOTNA UNIT 1 SOLDOTNA UNIT 1 SOQLDOTNA UNIT 1 SOLTOTNA UNIT 1 SOLDOTNA UNIT 1 SOLDOTNA UNIT 1 RRAGLEY UNIT 1 BRADLEY UNIT 2 ACE EXCESSIVE BRADLEY UNIT 2 ACE NORMAL BRADLEY UNIT 1 BRADLEY UNIT 2 BRADLEY UNIT 2 ACE EXCESSIVE RRADLEY U2 GEN FRAILEY U2 GEN RRATLEY U2 GEN MONE CHANGER TO INTRUSION INTRUSION ALARM FRI 2 ALARM PRI 2ALARMFRI2ALARHPRI ALARM FRI ALARM FRI ALARM FRI GOV HOLE GOV MOLE >]hoPDfhGOY MONE GOV HOLE GOV HOLE GOY MOLE BRKR BERKR BRKR LOALM 1 -215.0 LH -5. 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(o fee¥o torype ue (erEs Go rei 1O'71A 9 1o/ta v3 sarvde &2 arta say Gee G2 leeds oo! tO-tesie 1Gsteeds bospes'vo tae torte,co Poepecey torpscva 10/9892 10/14/92 WGALALS G: 10716792 LOT heonr 4g 114/92 Tn ee Pst eeG? a ee 10-26-99 ta perv Wate eo be paren 1.tare?edenee 10.18599 tae paren Magara 1O/T 92 10714/92 19/14/92 Pepe Poy 4eg2 195 pAr 9 fie parenpeepeegyIebeweoyeeo porta ey Orapede.92 pope ge feo.te ge es see Sted O9r35sa7 09338546 ovtayias 09339s4s 09s42551 09342352 09147523 09fagis7 o9sasisa Hereagat Ocrsaral OVEEGTAd OG TSGtaa neous O9ISGLI6NOSSO58 SeISotal OGIAGS4 DPINGIAL OEPoOsa Ok ae ty OPISotay ug pega? OoTKatay ovata LOHBu heLOi ovthoran OONSLEAG OOS5IT OFELIA OG aeL? OF Tho te taeOd O9Shaeh? OF? Ogle? OPI? ShBe CFI Ttk OVEGSaS OSsUlha? OOS Es OFFSAT2GOStSAsas OF F5ATSS OFsaaiad O9VTSht28 O9PSéETI? 98s? HEPA S Ie ost Oe gut OOPS OFTarrt Oey oes neees ee} A ACE NORMAL FOR TAGE RRADLET BRADLEY BRAMLEY 2 FRANLEY 2 RERNICE PAVES CR HAVES CE WAVES CF HAVES CF Paveg FF FEFHICR FOke 4 SOL DRING 4 PREAIN EY t FOR TAGE WANES CE AVES CK Waves Ck PEVES CF Wb e Ok [Aves Ck WAVES CR PAVES CE PPE TE FAR TORE POE TAGE PUR TARE WAVES CE FORTAGE PORTAGE FOF TAGE -FORTAGE FOR TAGE POR EAGE FOR TAGE FORTAGE PORTAGE FUR PAGE FUP LOGE FON TAGE FOR TARE BRAVES CK UNIVEFRS] FORTAGE UNTVERSI SOLTOTNA HAVES CE SOLTOUNA RRADLEY 1 WHTVERST VNTVERSI UUNTVERST UNIVEFSS UNDVERST UHIVERST WAVES CK WWYES CR HAVES CR (eepe FE SOE PATA | TULL GH ue tbte rer CS 2226 U2 866 FOrPOUT U2 TRIF HONE CHANGER T0 CONTROL RESUME UNIT 4 CALL O4 HES BREE 726 BEAR 72 ftS RUS VOLT FMA 11%RUS VOLT FHE {15 US VOLT FHA CS 206 tio BUS VOLT Vis eUS VOUT 1tS BUS VOLT Lot BOE YOALT 1S FS Ut VES RUS VOLS 415 6US FREQ OUCH TOESRY fF-F CS RIM HOFE?LINE HAL HOFFS FINE HOt HOFES FONE HOT SW 817 CS 2220 FHT FHI FH? FH tH Fae GIRDWOOD RY MONITOR GIRDWOOH BY HONTTOFR CS 2220 CS 2229 C§2220 HOFE RY MONTTOR HOFE KY HOMITAR FORTAGE KY MONT TOK PORTAGE FY HONTTOR GREWORDS TINE HET GEPWANDS LENE Hat POFE:UTNE HOI ANCH TESKY DE-EN STA INTRUSION CS 7220 STA INTRUSTON UNTT £HZ SW 715 L1SKYU N RUS HZ HOLE CHANGELt STA ST4 STA Sit Sit STA Wis 15 i iS) Vit INTRUSION INTRUSION THTRUS TON THTRUSION INTRUSION THTRUSTON BUS FREQ RUS VOLT FHS RUS YOLT FHO BUS VOLT Fd CANTRAL HOPE CHAHGED 10 HOLE CHANGED FQ MORE CHAHEEDT TA WE on 9 #00 0 bye mee ALARM ACKNOWLELGEL STATUS NOW STATUS NOW Nn pact STATUS NOW CHG VALUE TO JELF ALARM NORMAL (RIFFED VIG SCATA HEH A L2E.82 UM EDELS WAP FP P22.8T LM Pod.d HAL b t02.22 2H > bRAP PREG PEQK CHG YALE TO TRIE HIRST §47.42 LM TPES LOADM 1 67.62 1H 1He,% WIEST £64,40 LM 121.5 (QM §64,92 CH 106.5 HIRST 2 S905 PM ORD DLS(Och 2 59,55 LM 109.5 tOnla ft)50,90 LH 59,48 STarus NAW AL ARH TRIFFER YIM SCARA fraATUsS NAW NC STATUS NOW TES SvAlUS HOW ut CHE VALUE TO QFEN CHG VALUE TO CLOSE STAIUS NOW ALARM STATUS NOW NORA CLOSEN ==0YIh SCALA UNCOHKHMAND STATE TRIFFEL UNCOAMEAND STATE CLOSEEeStATUSNQUALARM STATUS HOW NORMAL STATUS NQW AL ARH STOEUS NOW NORHAL STATNE NOW na SiAves NAW FES STATUS NOW TES Sats NOW NORMAL STATUS NOW ALARM ALARM ACKNQULENGED STATUS NOW NORMAL LOALM 1°59,°0 LM o9.¢ CHG VALUE 10 OFEN LOALM 1 59.88 tM 99.9 Lori. STATUS NOU AL Aare STATUS NOW NORMAL STATUS NOW ALARM STATUS HOW NOR KAN, CUATS NOW ALARA STATUS NOW NORMAL GEORM ACKNOULENGED ALARM ACKNOM ENGEL ALARM GCKMOUL ENCE Te ALAR ACE NOWEEWEEte SuSE EMDR N STATION COMMUNICATION FAnI EF Cope --eweieeeeeeeeaeeaIe peeve 16716792 CO/EBF92 19/1b/S2 19/14792 HN/P Asan 19/3879 [Oe thsgo WastAary ae pore ryn Vaepergn Waite 92 fe.nn acd aeye re Paepsend fu-7s.cy te psevs 1a-1é-99 re a Mespeewe ineparsaGrya9 WTA gw? Warye saa Tae Lacqargo 19/14792 LO41A-oo Espero barges? 1o-geson P@etseaa Harp hee? Vae14-9? O14 GD 90/18/92 Leey grog 1H°06,992 taectasgo LG}4s92 LGeberog WOl1S 490 10°14 92 LOSps/99 WO-Ye OD lf 4so9 1G7}4/9) 14/16/92 ratpecgy Piegaces [pero luporc 10; 10; 10:0. 1O3G2501 10802005 10302349 WOOIIG3 UPR S| LGiOT as OeAyena POrGgee? COPE| Meoayad IGA? 1oroes|a WpoospstO1g9s6 porossos Parovsrs Lerapyne 1oyaesaa 103953U4 1OTGF IEG LO1OTISS Lotti PeLpesn2 Loritsas ariasrorsa TORRES TOs ETS) LOS 8887 WOMLayg? 1012357 lors? poryass? Lasissy? 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QUARTZ QUARTZ UUARTZ REL UGA KELUGH BELUGA REL UPA PER UIGA EELUGSH RELNGA BELT Bf fi C C ¢ C 8 G G LORST 1 59.97 LH ALARM ACKNOWLENGED CONTROL SUSFENPEN CONTROL RESUME) COMTE(H REStHE DE LOFST t =59.°R LM COHTEOE SUSE ERPS t VONTEOL RESUMEftPONTEOLRESUMELCONTROLSUSEERDF feCANTEOLRESUHETf COMEROE FRESUMED WATT PW? LPORV NM RUS HZ H#LOFK ACRHOWL EDGE ft OLARK ACKNOQULEDGCEE STATION COMMUMECATTON OLOEM ACKNOWLEDGE STA TNTRUSTON AUCH UESRY TE-Fe HORE?LIMP HOT GEUWOOES LENE OT PORTAGE KY KONT TOE HOFE BV KATTOF ERRE 474 FERRE 428 BERR 2216 BEBE 2286 RERR 220 BREE 2226 REEP RELAY FAIL LOSS QF MIR FRI SOULQTNA LINE FREA SW 2215 REKR 426 FH PRKE 626 FH BRAKE 426 FH FFRR 6246 FH FERE 626 FH BRRE 426 FH (oOedALARM ACRNOWLEDGEN ALGOEM ACENQULEDGEIt ALOEM ACKNOWL EUGE Tt GLORM SCKNOUL EEE AL OFM ACKHOULECGEE OLARA PE RHOULE REET CHE VALUE TO TREE TRIFRER VIA SCALA CHE VALUE TO TRIF TEIFFED VIA SCAG CHG VALUE 10 TRIF TRLEFEU VER COCLh 9.9 see ETATUE HOY fl ARM STATUS NOW AP AEN PQAtM 1 35.60 LH CHG VALUE TO OFEN LOALM 1 -9,29 1H 1O6¢H 2 -6.26 1h LOWH tt -G.08 tH 1HsIK 2 -6,29 1H LOAM -0.29 LH1 LOMMH 2 -G.29 1M CONTROL SUSFENTER CONTROL RESUMEte SW 2220 SU 415 FREE 626 FH t BERK 426 FH 2 BRAK 624 FH 3 MARATHON SETFT CNIRL MARATHON SEITET Furry UNIT fF GAS FLAY HARATHON CATEL SUF.|Ae MARATHOH SEIS CHO HARATHON GAS PRESS UNIT 3 GAS FLOW UNIT 6 BAS FLAW HAVES TE CALL LOR TE Cuan rere CHG VALIIE TO OFEN CHG VALUE TO OFEN AL ARK ACKNOWLEDGE! 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BERN2;3:4=0:0:15 B8RADL;2=25:10 COOP1;2=1;1 SOLD1=0 iJSILOS=15.0 MW 22SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE @SKV BUS.12/-0 FILE:CHANNELS\BERN2SKV.6BE xy FREQUENCY:......TEELAND 230 KV BUS 65.000 35.0001 ¥FREQUENCY:.......BELUGA 138 KV BUS -< 65.000 Xo x §s.000]in ¥FREQUENCY:MLP PLANT TWO 115 KY BUS _o 65.000 +os ss ste +55.000]©< y FREQUENCY:......BRADLEY 138 KV BUS tid 65.000 --->soo Ot x FREQUENCY:.....SOLDOTNA 315 KV BUS = 65.000 __--SoC 55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 o----55.000 ||||||g S ip "3 |ts ;o ty °FF 3 =_{2 if ° t ° 4 3 =_|se i® { i Ss =it _|s I x "3 if 3 -eS i "3 i Ww io os =|_ = |-* iT it 3 =i _!|° iT " t :ca) {4 L .-° \p " i q s = y -_|° So||a ||° |CASE6BE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:334%=0;0:15 BRADI;2=25;10 COOP1;2=1;1 SOLD1=0 ip WWSILOS=16.0 MW 2aJSCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/- 0 FILE:CHANNELS\BERN2SKV.6BE ROTOR ANGLE:......SOLDOTNA #}a 400.00 -7 400.0 TROTORANGLE:........TESORO #1!"Se 400.00 Ks x -400.0 =n ROTOR ANGLE:.......BRADLEY =!98) 400.00 tarts eseee +-400.0 G 2ROTORANGLE:........COOPER «1 rr 400.00 Devcescrceuccvcses Py -400.0 oO oO ROTOR ANGLE:.......BERNICE =4 2 400.00 _----CH -400.0 ROTOA ANGLE:.......BERNICE «3 400.00 ro -400.0 ¥<<|||T |||s s .e "$s Le 3 e 78 Nee ys 3='.°RO "0 wy &°Ye : -aN ae NS P s .xy we b=4Le"iO”T _|° xy " Y ©wo sé na 'Ny *.-*twa.0 '*o ud ww.®s = Ly 7 ied .°RO 3 NN . XQ Ss =MY -|° Ag " 2 yA 3 i.7 - hi : Ki|bei ||. CASE6BE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.5.00007.00009.0000TIME(SECONDS)3.0000OCT14199217:55BERNeSKV/6BEWED,BERN2;3:4=0:03;15 S8RAD1;2=253:10 COOP1;2=1;1 SOLD1=0 SILOS =16.0 MW 3 SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.6BE a ELEC.POWER MW:.....BRADLEY-2 100.00 nen 0.0 ELEC.POWER MH:.....BRADLEY-1 100.00 >a x 0.9 ELEC.POWER MW:......TESORO-1 50.000 tocccsaee +0.0 ELEC.POWER MW:......COOPER-1 59.000 Qe ccc crecsneeecene ry 0.0 ELEC.POWER MW:.....BERNICE-4 50.000 ----TT 0.0 ELEC.POWER MW:.....BERNICE-3 50.000 ------4 0.0 |||{|Poy:|re :|;fsI>jt :D Z 7 [poIfer.Vy ° Ix [{8 -I:oete|; : j ¢ , 1:it 6\| L:I:{3-I:T!2°Ix 77° :FiI[Ppr-.[)oo44:ia :L:|tebe7:$8 =J F +* 1:': v: Ix [1 }-t F _ Jpo \7 '° A \!3 -¢a or-_--a \7leyOXNav!!I'4y||})al--=yeeea---$He1.0000 ORVE Sv¥S 366BEANICEBERNICESOLOGTNA 0.0 -HOPE 3.0 sse8 9990 9909 ggyoetsc Os 3ege=0-0 499.9 |ne 0-0 go 0.0 : 0.0 °: )ee)0.0 1.001 =O):030 :14. 0.0 "13.5 eo goto svs H4.9 ao wieoz0.0]}|-0.0SS 0.8 5 -Fs ed to3.72.6 am )a)ck a OND S)So pio.2 , 0.07 >.xi: z -we eR@se{3 -§&= =8.7 $8 (OnTZ CR-6.5 nd 0.4 1.037 90.04.6 5.9 Sgeses -37.9 9987 tela.=°68 1.001 SKI MILL cc ccc cence csccnccesrcccvsercceccccrcscccesserserorcs 5.8 "13.5 64 72.1 ' 30.0 "a =28:5 LaWING le 2.5 1.930 SKI MILL Ig Hf 0387 1.037 "14.6 36 a?-ad9 -7.9 OnTz cn "XY 1.02 a 9993 |-13.3 ws I J 97 ©sotootua 'ZY 1.015 ao ws Tesono "2 1.000 95992 510.0 69 ol "13.4 = oo e= 7 coop LK S/O «1.025 a?<4 9991 vim -13.3 1,021 |83oatetae|SoLgoTNA aka es = 1 ©ow ow jo «lo 85 KASILOF BEAYR TP 1.00670wile rn ola ANCH PT 7 7S oS a rs iy adPmadCIRMROGol-1.047$965 aT 5.8--nl OS 3 s\ an ;wo zo zo r=) FRITZ CR BRAD LK 9997 500 27.1 $17.0-2.7 %(2) 19.3 -2.9 Sax -20.3 20.5 a 31.0 7)un 05 L.o}e.7 "4.8 "2.2 =°*.6-31 .o4e 1.050=7 "5.1 "2.6 Nnpn-|CRSE6CE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.pI BERN2:3:420;0;3 BRAD1]:2=30:17 COOP1:2=1:1 SQOLD1L=0SfeumeiWEO.,OCT 14 1992.17:59 KV:S69 .s138 .$230 |CARSE6CE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;:3;4=0;0;3 BRAD1;2=30;17 COOP1:2=1:1 SOLD1=0 S uwSILOS=16.0 MW tC) 1 SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/2O FILE:CHANNELS\BERN2SKV.6CE y FREQUENCY:......TEELANO 230 KV BUS a 65.000 nme 55.000]&> y FREQUENCY:.......BELUGA 138 KV BUS ened 65.000 Xr TX 55.000 7 1N v FREQUENCY:MLP PLANT THO 115 KV BUS _o&65.000 ose ssees +55.000 .<= y FREQUENCY:......BRADLEY 138 KV BUS aT 65.000 Deseretweeserneree +o 55.000 Oo oO y FREQUENCY:.....SOLDOTNA 115 KV BUS 4 65.000 __---55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 --------55.000 +?|||||g i s i.!-° 17 lx s =i}= i o ¢° 4 3 ie ° 's =iT aaif air=) it ef =:26 4 ou 'Ww i¢3 = ! 17 x 3 i|+:i t ° L if sa \ !s y P34 ||h |S .CASE6BCE:SUMMER.KENAI ISLANOED.BER-SOL-QRTZ 115 OPEN. BERN2;3;4=0;033 BRAD1;:2=390;17 COOPI:2=1;1 SOLO1=0 SILOS =16.0 MW SCENARI]O=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.1le/ FILE:CHANNELS\BERNCSKV.6CE ROTOR ANGLE:......SOLOOTNA 21 400.00 --»"400, ROTOR ANGLE:........TESORO st! 400.00 Ror x "400. ROTOR ANGLE:.......BRADLEY =! 400.00 tert rss +-400. AOTOR ANGLE:........COOPER «1 400.00 Orr reer *400. ROTOR ANGLE:.......BERNICE#4 400.00 --_r-rT "400. ROTOR ANGLE:.......BERNICE #3 400.00 ----=400. ¥< ,I ||| 6 x,\ i\BNLS\™ VY.%OX @ 4 ', AY e-.xs *s \\y aA*e %_SS.'"\''' e .*L_wy SON. \'. 'x *. .N-*\ 'S \ *"\'.BY L \N'po *.nN »* ryys i ot ||||bie i |10.0009.00006.00006.0000%.00002.0000WED,5.00007.0000TIME(SECONDS)3.00001.000018:09OCT141992BERN2SKV/6CE |CASE6CE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3:4=0;0:;3 BRADIL:2=30;17 COOPI:2=1;1 SOLD!=0 SILOS =16.0 MW 3 SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.6CE 18:10OCT14%1992BERNeCSKV/6CEWED,.ELEC.POWER MW:...,,BRADLEY-2 100.00 -- .ELEC.POWER MW:.....BRAOLEY-1 300.00 x rr ee ee ee D x ELEC.POWER MW:......TESORO-1 50.000 +--------+ .ELEC.POWER MW:......COOPER-!t 50.000 Qeccerenncccnecees Py .ELEC.POWER MW:.....BERNICE-4 50.000 __-_-SCo .ELEC.POWER MW:.....BERNICE-3 50.000 --------->r) *'5,|||'||iF i (8 |Eo. |.:re|1tle x |,tds::';|? i :|+TF :|:of ::4 -:|'a4 :|1 :'i :|'is -:|(HS x |;4 ;J -|en :i :4 ||bale :|;res -,a ,rotx:'I: oat f 'hd \of ve -.oy aeCaa\aarene =SRNT"co pod i a|||fl |;tli,,5.00007.00009.0000TIME(SECONDS)3.00001.0000 DAVE SvS 966ANICESEANICESOLOOTNAo5e0199909969sovooTic noreS.0 994 : 4.4%Pes |Sreran tecocoed =5 <0.0 ° >:0;998.0 .30 :-13.a8 "32 2 a "6 a aneox)0.0/-0.0°8 s slo elo2-208 ed 0.0/0.0 seed oo wio.2@+-sf wedge F300 S$MZ ™se aOR0.0 $e -y =o 3.5 |(at15.5 oe.2 2.3 1,036 case crri.7115.8 spokes -37, Leben Ce°8 1.016 SKI MILL «Jvc cee c cect cece wesc reset rete teens enettoectveesonsnees §.8-5.2 a4 =1.6 , -90.0ig 122 BNaa=1.3SKIHILLot0361.036 23323 98 Pi!d.2 wT gAatz cn YS”0.993 0)fF)9993 -i1.9 batt =bs *soLooTwA "SY 1.006 sl= dlic Tesoro wim 2.014 9992 -7.8 69 ti 5 5-3 cel mom ifin om + coop LK cic 0.993ao. vyv 991 rye 51.9 13577 °83737,KASILOF oloo4a"S|SOLDOTWA ake eo +=-oO)%3s-3S ojo Py 65 KASILOF BEAVA TP 1.004 70 <"7.4 aon win ANCH PT 75 " SSS Pa () o OrAM AOG "]1.0439965sil)-6.8 [n &:zn 2 zo ao ro) FRITZ CA BRAD LK 9997 00 12.12.0 0.8 71.3 2 12.8 =0.6 Sz "13.9 14.15.1 1Bes1.2 0.3 -2.9 Te4rs:0-3t1 044 =<="6.4 Naan ICRSE6DE:SUMMER.KENAI ISLANDED.BER-SOL-QATZ 115 OPEN.|¥-_|BERN2:3:4"0:0:25 B8RADI:2=15:12 COOPi:2=0:0 SOQLD1L=0Ptmeme|WED,OCT 14 1992 18:14 KV:S09 24138 .5230 |CASE6DE:SUMMER.KENAI ISLANDED.BER-SOL-QATZ 115 OPEN. BERN2;3:4=0:0;25 BRANDI:2=15:1l2 COOP1;2=0;0 SOLD1=0 0|SILOS =16.0 MW Ps SCENARIO=BERN2SKV:FLT/RCLS/PLT/OPEN BERNICE 2SKV BUS.12/© FILE:CHANNELS\BERN2SKV.6DE y FREQUENCY:......TEELAND 230 KY BUS nN 65.000 mee S5.000}gh y FREQUENCY:.......BELUGA 138 KV BUS 65.000 Mee x 55.000 x y FREQUENCY:MLP PLANT TWO 115 KV BUS -65.000 Homecare +55.000 2 y FREQUENCY:......BRADLEY 138 KV BUS 65.000 P eee 2 -55.000 o x FREQUENCY:.....SOLDOTNA 115 KV BUS = 65.000 -.-----55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 ---------as 55.000 ++|||rT 4 ||g |s ig "3s :co] .*|-_2° .foI 17 ik S Le i _I° i]o t o 4 sLeI_2° ip.* ° !° L 17 |e .& i ra} i]8s |+_|20 i "o i Ww i 6 gs =__{jet :ad I I]°lx 3 =i |© >mo t °4 4 =i aebes a9 S s _My -_|2° ||S BERN2@SKV/6DE |CASE6DE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3:420:0:25 BRADI:2=15:le COOP1;2=0;0 SOLD1=0 SILOS =16.0 MW |SCENARIO=BERNOSKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.6DE ROTOR ANGLE:......SOLSOTNA #1 400.00 -»"400.0 ROTOR ANGLE:........TESORO at 400.00 Mere x -400.0 ROTOR ANGLE:.......BRADLEY 21 400.00 tar ere eee +-400.0 ROTOR ANGLE:........COOPER #1 400.00 Derr cree rnvecesece o -400.0 ROTOR ANGLE:.......BERNICE #4 400.00 -_--_-rT -400.0 ROTOR ANGLE:.......BEANICE «3 400.00 --_-400.0 ¥+ |||||| g K Es - a PS we =)*,'- \oN oO\.,'\ Noo Noy =Yoo y 4 \x ' Qo Vk \'.A _-Noes ? 4 weNolNoo 6 =N oN Nae NOUS NUL N'x ad N- -_ Wes, oad XN '\-_ \ Ve VN =\you 1}| bye rte|||beet |10.0009.00008.00006.00004.00002.00000.0WED,5.00007.0000TIME(SECONDS)3.00001.000018:25OcT141992BERNeSKV/6DE |CASE6DE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;334%20:0;:25 BRADL:2=15:;l2 COOP1;2=0;0 SOLD1=0 SILOS =16.0 MW |SCENARI]O=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/ FILE:CHANNELS\BERN2SKV.6DE ELEC.POWER MW:.....BRAQLEY-2 100.00 -r c.0 ELEC.POWER MW:.....BRADLEY-1 100.00 Mrs x 0.0 ELEC.POWER MH:......TESORO-1 50.000 tree nse +0.0 ELEC.POWER MW:......CDOPER-1 50.000 Qe reecetenereeccae ry 0.0 ELEC.POWER MW:.....BERNICE-4 50.000 - --"_----0.0 ELEC.POWER MW:..... BERNICE-3 50.000 ------_0.0 +9 ++||ly ||,-Yt 8 i |:3 \ y 'e =\:|'_! \:||:' ° .'°o )'$ |1 .|'_|s ; ;|H o t °|'> 4 COE -|lao 1 :|' {:|2 =i]: I '-*.x || i SoG }t =!:|'-> 4 7 by \:|; 'Spt te =/:|'_/e !'* \:' }-$4 =7 *\'_] t sat .ofr |)('sA-7 So -7 cad :'te _Ie _Suh SsComeovasroOo -_” *oN an _-7 ---- .T -- ||: ||||||di:fs 5.00007.00009.0000TIME(SECONDS)WED,3.00001.000018:25OCT141992BERN2SKV/6DE BEANICE SEANICE SOLDOTNA 9998 19990 9969 soLootic3.0 |0 9994 :6.0 >Sc ccc ccc ce ccc cnc ccersccced - - 0.0 : i0.0 1.010 ;wah. 0.0 8.7 2 SOLD Svs 73 Slo o z )0.0 20.0758 0.90 §-<je alo378;«”0.0-0.02°9 0.0 nwo 34920.20.0 aoe!coe 3.0 e rz -we 200.0exe|3 -y =o 0.8 0.0 (aq?cA5.5 eet 71.0 1,038 0.0 gag)© 1-4HS.8 =-3?.jbatodes°3 1,010 Ore a 6 5 a |6.8 -8.7 et 1.8 -30.0 1.9099 -19.%9996aQ.4 1.003 LAMWING SKI HILL SIN =Hf}030 1.036 -14.0 8 Ts -d.2 7.2 ontz cn YS”0.997 m TS 9993 -12.7 aj 'wlio owiaohoe.rywnlesovootwa"XY 1.010 s-=eTESOAO|1.009 9992 59-6 69 1 =8.8 ns ibe ow Min boas bhd "2 tJcoopLk"ig 0.997 .vx 1.0525 3931 st2.7-30.01,050 a 8340.-_KASILOF " io own bry woe'!SOLOOTKNR Xn Yr ee =|-1 ”a2 3S o o|o 0s KASILOF BEAVA TP 1.005 70 -6.9=--- oon ou 80 BERVR CR ancH PT 1,044 75 ws 6.4 S=- 7a ' 86 0 06 ANCh PT 1.0485 =6.0 z Oo cney-)xo eo So FRITZ CA BRAD LK19997500 19.2 ok 12.0 ©)"1.7?ve -1.8 2 15.8 e1e? cy "17.0 17.2 oS 25.2oe 1rimSpfteetet 3.9 -1.6 r@ i ©O.3Uy 046 1.099 <-5.3.4 Naps CASESEE:SUMMER.KENAI ISLANOED.BEA-SOL-QATZ 115 OPEN.pe IBERN2:3:4%20:0:15 BRADI:2225:12 COOP1:2=0:0 SQLD1!=0EyumesWEO,OCT 14 1992 18:29 KV:s69 25138 .$230 |CASE6EE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:3:4=20;0:15 BRADI:2=25;12 COOP1;2=0:0 SOLD1=0 2SILOS=16.0 MW - J SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKY BUS.12/2 FILE:CHANNELS\BERN2SKV.6EE ¥FREQUENCY:.22-2 TEELAND 230 KV BUS nu 65.000 -55.000} x FREQUENCY:......-BELUGA 138 KV BUS ” 65.000 Kor x 55.000|= y FREQUENCY:MLP PLANT THO 115 KV BUS _65.000 tre t eras +55.000 | y FREQUENCY:......BRADLEY 138 KV BUS ° 65.000 Sn =S001 2 FREGUENCY:.....SOLOOTNA 11S KV BUS .% 65.000 -----o 55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 ----a 55.000+l T rT |||||giS ie "3LWS i a o if \x 3 =i _l° i]° t ° 4 =/-i _|° ie * !° {S =iT _|eitoo! i g iy 23fa =2c 4 a i WwW If s = if I+3 =i +° if . t :c J 4 S =)4s 0 " S \3 t s oe|1 A |S BERNeSKV/bEE |CASE6EE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:3:4=0:30:15 SB8RAD1;2=253:12 COOP1:2=0:0 SOLODi=0 >Lu|SILOS =16.0 MW ve LL SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/2O FILE:CHANNELS\BERN2GSKY.6EE ROTOR ANGLE:......SOLDOTNA st u 400.00 -400.0 T RSROTORANGLE:........TESORO #1 mead 400.00 Moo x -400.0|=IN ROTOR ANGLE:.......BRADLEY a1 a) 400-00 $ocoeseee +"400.0 |©= ROTOR ANGLE:........COOPER #1 °WW 400.00 Oe ccccercrcrevccce Ps -400.0 oO cO ROTOR ANGLE:.......BERNICE «4 = 400.00 ------400.0 ROTOR ANGLE:.......BERNICE #3 400.00 ----s 400.0F$- ||||}||S S e "3s f=)'.So |an 5 5 °o x S °o +0 ¥ X,> %8 pene Ny _]°a e %, yy ° Qe S *.}3° -Nv "lo"-A ran)q sZ =SS q ares x Ww**s,f 3 =Le NY oe wn * s % *e,$ mend AA --°*" %\.@ °o ®,= =,4" 'Ob Nu y = Iys S i "|7 be thbhi |l S |CASE6EE:SUMMER.KENAT ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:3:4%=0;0:15 BRAD1;2=25;12 COOP1;2=0;0 SOLO1=0 SILOS =16.0 MW }SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.6EE 18:41OcT141992BERNeSKV/6EEWED,.FLEC.POWER MW:.....BRAOLEY-2 100.00 or mm r .ELEC.POWER MW:.....BRAOLEY-1 100.00 x es x .ELEC.POWER MW:......TESORO-1 50.000 Parcseaae + .ELEC.POWER MW:......COOPER-1 50.000 Stns = .ELEC.POWER MW:.....BEANICE-4 50.000 __ -3 .ELEC.POWER MW:.....BERNICE-3 50.000 ----s ||||cn ;|:i.|' -V pos 1:{I:ro:Ix ' t-|' 1 jo +7 -I.|; I ;ot I:|: i {ee I 'ix ' I:|i1:|fy --I ,4 &| 1 |; !:,ot -L-|: 1:' \:| Vx |: -f .' ,|4 V o- -ie i )vae--c rms _Se' -_7 _=«=T cm !| ||l l Le i dt 6.00007.00005.0000TIME(SECONDS)2.00004.00003.00001.0000 DAVE Svs BEANICE BEANICE SOLOGTNA ,- 9986 990 $969 sovoris S34 Teg 9 NObE3.90 9994 °Fe Ge-0-0 :OOp >FS ccc ccc cc ccc cor esccrercscved oO.oo 70.0 : 9.0 °:EI,ooo SSE 352080.0 .997 901.000 :715. 9.0 -13.7 o $ou°svs -45.9 7 ae°Zz )0.0 a0 oS 0 s ee slo slo 3.7 R$a”0.01-0.038%0.0 ow 20.2 '' 0.08 2...93-05 <"EZ -we Est 4@etf-%"3 g s -3.4 :(-6.5 a 4 0.3 1.031 Jo-0 QATz cA5.5 S.9%pokes -37.8 Lele Ce°& 0.997 SKI MILL ccc cece e ete c cece c eter ers ceesecercesesceetetteteas 6.6 713.7 ay "1.8 . -9).0 1.on 99 -27.9 9996 a 1.9 1.001 LAWING J . SKI MILL M5 =3°3!1.031 "15.5 $6 onl mi .7 -7.6 ontz cn YX”0.995"l=9993 "14.2 a6 r so o)s sovootwa 'SY 1.008 -oleTesono"I5 0.997 9992 69 -13.6 o* oon 2iv a a q ocoopLKSl (8.995 RY 9991 ofr it.2 13874 0}63-45,a > ss RASILOF °;SOLOOTNA ak oli is mh 1 La oo t )i ]oe ole 8s KASILOF BEAVA TP 1,000 76 "11.2 on ola ANCH PT 75 Ones OIAM ROG Cis 1.0849965= t<] x o cm wo zo ag o FRITZ CR BRAD LK7500 28.6 KS 19.0 ©)-1.7 re -1.6 2 19.9 =2.6 c+=21.0 21.3 at 31.2meSosL2ilze+ 4.5],met <Dcee0.3 a 1.045 1.049="4.8 2.2 Nanna CASE6FE:SUMMER.KENAI ISLANDED.BER-SOL-QATZ 115 OPEN.|__|BEAN2:3:420:0:3 BRAD1;:2=30;19 COOP1:2=0:0 SOLDI=0emeiWEO,OCT 14 1992 18:45 KV:s69 .<138 .4230 |CASE6FE:SUMMER.KENAI ISLANOED.BER-SOL-OQRTZ 115 OPEN. BERN2;33 %4=0;0;3 BRA0O1]:2=30:19 COOP1;2=0:0 SOLD]=0 4 luSILOS=16.0 MW we LL |SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2@SKV BUS.12/2 oO FILE:CHANNELS\BERN2SKY.6FE ¥FREQUENCY:......TEELAND 230 KV BUS a 65.000 me »$5.000 pas > v FREQUENCY:.......BELUGA 138 KV BUS ad 65.000 Xo x §5.000 7 Ln y FREQUENCY:MLP PLANT TWO 115 KV BUS ov65.000 Foss sssee +55.000 S < y FREQUENCY:......BRADLEY 138 KV BUS a 65.000 Qe cc ener venancees Ps 55.000 oO oO y FREQUENCY:....,SOLDOTNA 115 KV BUS 4 65.000 __--+r 55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 ----s 55.000 -o-|[_-T i ||||: |so ie "Ss =1&8 .fondi |5 I s =i _l2 it < ¢° : S =_|® Ix -_-- :na| Oo ssLe¢co : T wn Wl 4 ”{Ww ioe S = =i ne; if I s =i _}° i]” ¢ i 4 \ |s \S fo]|1 || |CASE6FE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3;4=0;30;3 BRAD1;2=30;19 COOP1;2=0:0 S0OLD1=0SILOS=16.0 MW J SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KY BUS.12/ FILE:CHANNELS\BERN2SKV.6FE ROTOR ANGLE:......SOLOOTNA st 400.00 --400.0 ROTOR ANCLE:........TESORO #1 400.00 Keres x -400.0 ROTOR ANGLE:.......BRADLEY s1 400.00 terre rcreen +-400.0 ROTOR ANGLE:........COOPER «lf 400.00 Qe rcsceecereascoes o -400.0 ROTOR ANGLE:.......BERNICE #4 400.00 __----To -400.0 ROTOR ANGLE:.......BERNICE #3 400.00 a -400.0 ¥.° t ||||g o b " } ° S ° --s \> & Tm |.-_- '.\Oo. N S ON t 3--',\meas Fr)KON 'MOON*e AYLSS ¢ - *e '"%N%N o 3 S "2 -MS '\"ss'N " N > wy = . -_ oN Vv \f ° "oN S ='\_j2 SON " MN »\ amend '\ rfrs od .°|hk 7 |||°o OCT141992BERN2SKV/6FE5.00007.00009.0000TIME(SECONDS)WEO,3.00001.000018:56 1 CASEGFE:SUMMER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:3:4=0;30;3 BRAD1];2=30:19 COOP1:2=0:0 SOLS!=0SILOS=16.0 MW }SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.6FE ELEC.POWER MW:.....BRADLEY-2 100.00 anes al 0.0 ELEC.POWER MW:.....BRADLEY-1 100.00 x ee ee es x 0.0 ELEC.POWER MW:......TESORO-! 50.000 Her ersren +0.0 ELEC.POWER MW:......COOPER-1 50.000 Dec cccceeecercveee Ps 0.9 ELEC.POWER MW:.....BERNICE-4 50.000 __,-_---=0.0 ELEC.POWER MW:.....BERNICE-3 50.000 ------a 0.0 ||||T r Ti 4fs :|:tlc :|ie ee *°':-_lJ :{; :!ane "|YS ,||,|nl :4 La °|'-L |1¢ ;!He :|'2 =:'Ue x l ie ;|;||t -|>? |:Ne en:='45 ,|'ni |!; x |rod =:be i 'l ('|Te L ?:AS .ee |2 wu¢_e =4)4rT| boo||||||||eee &18:57OCT141992BERNeSKV/6FE5.00007.00009.0000TIME(SECONDS)WED,3.0000$.0000 OAVE SvS 306ANICEBEANICESOLOOTNA55069909989soLooT1G More a a99998' Le |RP SS |of fone 1): 0.0 \E+454 He:9.0 0.99 .718. 0.0 -10.6 °SOLD SVS a eo )g.0}0.058,¢fo.8 s slo cic 3.9545 a”0.010.02%O20 . '' 0.8 Ree 3.656 WZ ™: 0.0 -¥S 3.6 0.0 (2.2 a3 ¥0.1 1.017 0.01.7 8.8 pesos 40. 2.058%Ce°6 0.999 SKE MILL We cee ecco nec ce er eectenscunspenestetetenttnters 8.4-10.6 84 "1.5 aa Laiev1.4 1.014SKIHILLa1.917 -18.3 <_"10.QATZ CA -009 =9993 F at Se 7 bc be le sotpoTNA "EY 0.990 a a KegTesonO='NI 0.997 9992 sit.8 69 rte -10.7 > os wn slo coop ux SI©1.012 .ye 9991 ue -16.7 49°3 83--yesator SOLOOTWA an @ 7]3 3% BEAYR TP 0.984 70 "11.9cS-> ce] ol= 80 BEAVA CR >AWCH PT Tle 1,022 vedOramROGTS 1.0249965Psi-9.2So jr é -poe .=x 13.2)Ty'zo 8 4.3a FRITZ CR BRAD LK999S00 23.8ll os 33.0 oa;1.8 © 21.2 tel ew -22.9 23.2 eS 16.3 {)nos 1.8}f-1.5 -0.3 ied 1.6 |2°a:9-5b1.028 1.041="8.-S.7 Myrwn-j CASE AE:WINTER.KENA]ISLANOEDO.BER-SOL-QATZ 115 OPEN.p__-.|BERN2:3:4=0:0:25 B8RADI:2=20:31 COOP1;2=1:1 SOLDI=0fEmemetWED,OCT 14 1992 19:01 KV:S69 .s138 .5230 |)CASE7AE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.BERN2:3:4=0:0:25 BRAD1:2=20;31 COOP1:2=1:1 SOLD1=0 =WwW SILOS =20.0 MW - c 1 SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2@SKVY BUS.12/a ™ FILE:CHANNELS\BERN2SKY.7AE ¥FREQUENCY:......TEFLAND 230 KV BUS a 65.000 ---r §5.000}&> y FREQUENCY:.......BELUGA 138 KV BUS "Se 65.000 Xe r ee x 55.000 rin y FREQUENCY:MLP PLANT TWO 115 KY BUS _o@65.000 orcs +55.000 .< y FREQUENCY:......BRADLEY 138 KV BUS 65.000 Dever ecncreerneee >»55.000 oO CO y FREQUENCY:....-SOLDOTNA 115 KV BUS = 65.000 -_-SS o 55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 --a 55.000 <¢-t||--|||g y !Se,!: .a |fT (¢sLei_I°wm t ° f=]fo ;S i ©* }° !-] =i _|s i ¢ea o-i sz 'e9_.sa wu 4 9 |Ww i 6 s = :o = rv \°{1 x 3 i m ¢ g Z ' 7)" ' \s = \_/> So||h || |CASE7AE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.19:11OCT141992BERN2SKV/7AE5.00007.00009.0000WEDTIME(SECONDS)'3.00001.0000BERN2:3:4=0:0:25 BRAD1;2=20;31 COOP1:2=1:1 SOL01=0 SILOS =20.0 MW J SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.7AEROTORANGLE:......SOLOOTNA =I 400.00 _--_r -400.0 ROTOR ANGLE:.,......TESORO at 400.00 Kose x 400.0 ROTOR ANGLE:......-.BRADLEY =! 400.00 tere rere +-400.0 ROTOR ANGLE:........COOPER at 400.00 @ecccacocecscccsee 2 -400.0 ROTOR ANGLE:.......BERNICE #4 400.00 - rrr or -400.0 AOTOR ANGLE:.......BERNICE «3 400.00 ----s -400.0 %2|I ||||g :° é = 2 .| = | - | t _8 x " =- ana =Noteb.aANes,ls Nese, NOX, SeNSeMise, =Neste,-NoNoNe, w se.NS o.2 =ae S 'on a " NV a ee ae 4 ©||mx +©||o |CASE7AE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3:4%=20:0:25 BRADI;2=20;31 COOP1;2=1;1 SOLD1=0 SILOS =20.0 MW J SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE eSKV BUS.12/ FILE:CHANNELS\BERN2SKY.7AE 19:11OCT141992BERN2@SKV/7AEWED,ELEC.POWER MW:.....BRADLEY-2 100.00 rnee .ELEC.POWER MW:.....BRAOLEY-1 100.00 x ee es x ;ELEC.POWER MW:.....»_TESORO-1 50.000 terre ern + .ELEC.POWER MW:......COOPER-1 50.000 Dore ncecccecceacce Py .ELEC.POWER MW:.....BERNICE-4 50.000 - -TT .ELEC.POWER MW:.....BERNICE-3 50.000 J Lae ||]|,|| \:' \i i L--*\|: \:' an -i & ={:': '|:+° !|:: 3 |:: =i |:' i i :'bh I ' ; J {°2 i I i :!. I . '|° !|t Le J \ :'pod t |:' !:i -t |:' ):' 1 :' }1 x ' -/\.t \|' \'°Pan :§ =c D *s Teok<se h -----e z +"sk <<ec” 'i.T i || |||\it L.ti 5.00007.0000TIME(SECONDS)3.00001.0000 DAVE Svs 906BERNICEBEANICESOLDOTNA 0.0Pcl)-HOPE 5.0 see 9990 9969 so5g071s Ot 3egs-2-0 49CTaa|ee SA |(a 0-0 oo.0 : 0.0 °: 0.8 Be],ore 888E L818:0.990 801.013 :20. 0.0 -14.8 22 soy°Svs =50.0 en o x 0.00.0 0.0 <ac «ajo 3.98 $n )F 0.0 ORR:0.8 S)ae Repe.2 '' 0.0}.By...J3-6 %"Ez -win 300.0@esf3-§=° a8 g.8 (QAT?CR2.3 oc 1.3 1.013 Pod 39875.1 0.8 ised -40.8 2.len oe°8 |e rr 19 Op 0 Ss |a 8.4"14.8 "1.5 -30.2 9998 Q.t 1.014 LAWING ral - }SKI MILL 1.013 -19.6 38 !710.8 entz cn YS"-s 1.009 { 9993 -17.9 ball hake onaleso.ooTun VEY 0.999 we ain TESORO ls 0.989 9992 513.0 69 'js =14.8 > -_c n a coop LK S/@ 1.012 .yw 991 wer -17.9 19°"83---KQSILOF SOLDOTNA ye oNciaziov---1 °34%° 8 BEAVA TP 0.962 26 -13.6 7 > 80 BEAYA CR ANCH PT o21 7S .3 to OIRAM ROG _le;2.623 $96S =U -6.7---- orm x -zoo.ey 13.2)7'xe 8 4.3r=) FRITZ CR m 9997 nao LK ar.ol|o¢31.0 o.6l|<1.9 2 24.4 Q.2 cow -26.2 26.5 $26.9were$1.8]/-0.7 -0.8 ve 308 (1) 5°:0-501 .027 1.041a-7."4.7 Napn_|CASE7BE:WINTER.KENA]ISLANDED.BER-SOL-QRTZ 115 OPEN.PI BERN2:3:420:0:315 BRADI:2230:31 COOPI:2=1!:1 SOLDI=0[EeeesdWEO,OCT 14 1992 19:15 KV:s69 .5138 .<230 |CASE7BE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3:4=0303;15 BRADI;2=30;31 COOP1;2=1;1 SOLD1=0 0 utSILOS=20.0 MW © 1 SCENAR]O=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/" FILE:CHANNELS\BERN2SKY.7BE v FREQUENCY:......TEELAND 230 KV BUS ua 65.000 rr 55.000]th y FREQUENCY:.......BELUGA 138 KV BUS "ey 65.000 Xoo x,55.000 Tin y FREQUENCY:MLP PLANT TWO 115 KV BUS _a65.000 Hes ssecee +55.000 o = v FREQUENCY:......BRADLEY 138 KV BUS Ww 65.000 EPP EPEPEESEE =557000 ao y FREQUENCY:.....SOLDOTNA 115 KV BUS 2 65.000 _----+o 55.000 v FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 o--a 55.000 ++°|||i |||8 i so i ¢"s =S o if 1 x s =i aa be:oO i t ° :: = i ||: j :f=} }s =i fT 2 i x ° O i eZ =:mep- ]wm W 4 9 &3 = =joe i r 1 ft i : =j _|¢ 1 mn ? |g Z ;_E )ry N '$ !3 fo]|||yt ||° |CASE7BE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2;3:4%=0;0;15 BRAD1:2=30;31 COOP1;2=1:1 SO0LD1=0 oO lw|SILOS =20.0 MW -CO SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2S5KV BUS.12/cmt FILE:CHANNELS\BERN2SKY.7BE ROTOR ANGLE:...,..SOLDOTNA 21 uo 400.00 -r 400.01 ROTOR ANGLE:........TESORO #1 mead 400.00 Xo x -400.0 ate) ROTOR ANGLE:.......BRADLEY =!a0) 400.00 a +=400.0]o =ot ROTOR ANGLE:........COOPER «1 tu 400.00 Qe rece cccecocescee ry -400.0 oO co ROTOR ANGLE:.......BERNICE s4 = 400.00 __----o 400.0 ROTOR ANGLE:.......BERNICE #3 400.00 ------400.0 ¥=--|||||$ ° 6 "Ss oOL ]a_i -o } °o x b=4 =_je __ | |& Z i _& x °n if °Fso =ee me,we 7 o uJ =ae jeBQ,> ma, Se TR s =tho._|2RO,m *.oe"a "e, are S -a me -¢ "\@.* Se \: =yO._}°ea- } ||bh 6 |||S 1 CASE7BE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BERN2:3:4%=0:03;15 BRAD1;2=30:31 COOP1];2=1:1 SOLD1=0 SILOS =20.0 MW SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/ FILE:CHANNELS\BERN2SKV.7BE ELEC.POWER MW:.....BRADLEY-2 100.00 ee em ee 0.0 ELEC.POWER MW:.....BRADLEY-t 100.00 Xe x 0.0 ELEC.POWER MW:......TESORO-1t 50.000 Hose cence +0.0 ELEC.POWER MW:......COOPER-1 50.000 Qe cee e rece ceeee 2 0.0 ELEC.POWER MW:.....BERNICE-4 50.000 -_------=0.0 ELEC.POWER MW:.....BERNICE-3 50.000 ---0.0 ||||an ee i713pooids |\ |!po '''To|x!AS =::1 'a befoone J :oo ¢;4 ; =|;''4 |1 ;7 yo le ;i ''lg =|f ;_l2 peor GP :.J ':[|oo to -por i j to|:!'le |}.;OB --7 oF :7sfoupot': [x po =4 += ;':|'tle =Sz Lis yy »=So)-"5 _#J an oN wo”- =_-*-ss J if |! jlo:'||||||Lie WED,5.00007.0000TIME(SECONDS)3.00001.000019:26OCT141992BERN2SKV/7BE DAVE SVS BERNICE BERNICE SOLDOTNA 9306 99668 19990 $989 SOLOOTIGCyaeeee|rs 2.so" 0.0 6.0 . 0.0 °585e =souo svs asz0.0 2-9 eg -0.06 ajo3.92 -")|0.010.087 0.0 0.6 2)3.7%WZ - 0.0 -ui -3.6 0.0 (-9.7 eke 1.9 0.995 p9-907.48.8 shese's 41.9 201R Oeo6 10.95 SKI MILL Yaa eee cen cence cutee rere ac crecceecrcaeseeneceeseones 8.5-20.6 a4 "1.5 -39.0 9996 0.9 1.006 LAWING 0.995 722.3 "11.9 ontz cn "S"1.001 q 9993 -20.7 mw oe SOLOOTNA od en bgTesono=j,2 0.95 9992 69 '-20.5 a f-)-[as slo wlo "' 7] coop LK SIT 1,006 VEY FD ee ees 20-©15895 83 S2.KASILOF 7]4SOLDOTNA<12 1%=ye oN qd)ou oro oo .ce be BEAVA TP 0.958 76 =L -ie.-_oool> ANCH PT 75 OTAN nos le,1.0139965=-6.7 pe :_ 17 ee i321 4°ze 8 4.3Py FRITZ CA BRAD LK19997500 40.4 aS.31.03.1 3 G4 ©)28.8 0.3 cow -30.6 31.0 4S 40.9meBe1.8]|-0.6 =O.aT 4.8 @)=?o-51 .o168 1.095 to ™He wd Kar CASE7CE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.BERN2:3:4%=0:0:3 BRAD1:2=42:31 COOPI:2=#1;:1 SOLDL=0[rmetWED,OCT 14 1992 19:30 KV:$69 .S138 5230 |CASE7CE:WINTER.KENAY ISLANDEO.BER-SOL-QRTZ 115 OPEN. BERN2:3;4=0;:0;3 BRADI;:2=42:31 COOP1:2e=1:1 SOLD1=0 s UWSILOS=20.0 MW ee CO) +SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/om FILE:CHANNELS\BERN2SKV.7CE y FREQUENCY:......TEELAND 230 KV BUS au 65.000 mee 55.000 |&cC> y FREQUENCY:.......BELUGA 138 KY BUS YY 65.000 x a ed x 55.000 all wn y FREQUENCY:MLP PLANT THO 115 KV BUS _a65.000 $oscccees +55.000]&< y FREQUENCY:......BRAOLEY 138 KV BUS arr 65.000 Desc cc cece rcv cence Ps 55.000 Oo co x FREQUENCY:.....SOLDOTNA 115 KY BUS = 65.000 __-_--lo 55.000 v FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 a 55.000 ¢$°||i {||3 6 3 =i 3- 2 i ft i +s =i ° i le t © 4 S =1 _!Ss i 9 . |°i a i ¢s 1 ¢e . :Nn!-i Lo] _'£9 1 "8 j ws i oo s =:L ] , 1 ft i s =i _/° i mm t :So 4 P4 =\-_j2% 1 " \ S = \8 oS||||h ||= |CASE7CE:WINTER.KENAI ISLANDED.SER-SOL-QRTZ 115 OPEN. BERN2;3;4=0;0;3 BRAOI:2=42;31 COOP1:2=1;1 SOLDI=0 SILOS =20.0 MW SCENRRIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/ FILE:CHANNELS\BERN2SKY.7CEROTORANGLE:......SOLDOTNA #1 400.00 ->-400.0 ROTOR ANGLE:........TESORO al 400.00 x ee ©©oe ee ee x -400.0 ROTOR ANGLE:.......BRADLEY s! 400.00 Porterseen +-400.0 ROTOA ANGLE:........COOPER sal 400.00 Qrvescvcrscccrovcs Ps 400.0 ROTOR ANGLE:.......BERNICE #4 400.00 - -7-7 7 400.0 ROTOR ANGLE:.......BERNICE #3 400.00 8 -400.0 =||TT ||||g ° b = + S -g a 6. ] _J. =- SOM, .O™s os |3 -w0™.ss: se..> Sa.0N"SN,t A:.™".SK eg, -"LUN -RN, re See SL eN ° |3 LO”,°o a or By.|" *d ' oN ='.' 1 ot 7 '7 I : |L |tix §||&19:41OCT141992BERNe@SKV/7CE5.00007.00009.0000HEOTIME(SECONDS),3.00001.0000 CASE7CE:WINTER.KENAI ISLANDED.BER-SOL-QATZ 115 OPEN.Ninn BERN2;3;4%=0;0:3 BRAD];2=42;31 COOP1:2=1:1 SOLD1=0 Su'CMMILODITS.|SILOS >20.0 MW goEe|SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/7 = FILE:CHANNELS\BERNGSKV.7CE , .ELEC.POWER MW:.....BRAOLEY-2 a 100.00 -mr 0.01 &> ELEC.POWER MW:.....BRADLEY-1 "Fe 100.00 x eo ©eo &&oe x 0.0 =Ww ELEC.POWER MW:......TESORO-1 OM 50.000 tesco e >0.0]o 2ELEC.POWER MN:......COOPER-1 a uJ 50.000 Sooo >m0 ao ELEC.POWER MW:.....BERNICE-4 * 50.000 _ ----Co 0.0 ELEC.POWER MW:.....BERNICE-3 50.000 ------<£-_a 0.0 |"|1 Ti fs :|i ds. :|7 8T:|TT ¢ :!PTS a °|(8 :|+Te :|,o} ;;Fs -|!i oe |/8=:'a be x |fos :|+|g | :|;af 8 oO:|':w WwW ,= .|fw -a: x |/1 8 =:'-_j]°|ne 'cq (H 'Ne .':PS a Z :satS"oea.VZlesy5$ -r iva|ae an ne |||.l lig ie BEANICE 9988 BEANICE $90 SOLOOTNA 4989 DAVE SvS 306 nore °govooric 49Foeeeeeaa|nee --of-fe-e_(7)0.0 : :0.940) 0.0 . :-19.3) 0.0 2 oye SvS -49.3 mo yo 0.0/|-0.¢0.0 «-asic ale2.985 )0.0 -0.0n%0.0 S)os Zepio.2 1Qye-t|..d...3.6%we 200.0 0.0 -3 o 2.8 0.0 (2.3 o 0.6 1.003 Jo.0 OnTz CA3.9]0.8o8 -40.2aSag so cueccceocccescacccaseceeccctrccsccuastsetenensecees 8.50;991 SKI HILL sits ' 75 24.6 9996 "3.4 O.94%}LAM ING SKI RIL 7009 1.003 -16.9 0.2 "L062 ontz ca "SY 0.998 { 9993 -i7.0 ml so.boTwa "YS”0.973 so loTesoro«(MI ,;0.989 a992 sil. S ™x tied pe be ow Aan 7A ajols: coop LK Sl 0.938 .wy 1.0812 9991 ofr -17.01.004 a me3 ein KQSILOF ”:SOLDOTNA Ra a a 2oO)5 72 32 =io KASILOF BEAVA TP 0.969 7 "12. ANCH PT 75 rn orAm AOG =;1,016ay 8.9 aoxaPdey213.2)THzspestis -2 [-] FRITZ CR BRAD LK9997S00 25.21 o¢33.03.1 *S 3.7 2)22.0 2.0 fia -23.8 24.1 $16.6ars$1.6][-2.5 0.8 ss 3.5 1D)zs =®-Sbi 020 1.037=-6.2 "5.3 ran_|CASE7DE:WINTER.KENAI ISLANDED.BER-SOL-QATZ 115 OPEN.'BERN2:3:420:0:25 BRADI:2=20:33 COOP1:2=0:0 SOLDL=0EmelWED,OCT 14 1992 19:46 KV:$69 .3138 .s230 nn CASE7DE:WINTER.KENAI ISLANOED.BER-SOL-QATZ 115 OPEN. BERN2;3:4=0;0;25 BRADI;:2=20:33 COOP1;2=0;0 SOLD1=0 SILOS =20.0 MW 10.0009.00008.00006.00004.00002.0000Es]SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 25KV BUS.12/ ,FILE:CHANNELS\BERN2SKY.7DEx.FREQUENCY:......TEELAND 230 KV BUS 65.000 cme 55.000 y FREQUENCY:.......BELUGA 138 KV BUS 65.000 Rr se x 55.000 yv FREQUENCY:MiP PLANT TWO 315 KV BUS 65.000 herr rerne +$5.000 y FREQUENCY:......BRADLEY 138 KV BUS 65.000 Docc ce vensscsccece rs 55.000 x FREQUENCY:.....SOLDOTNA 115 KV BUS 65.000 __-_cr Tro $5.000 xv FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 re)55.000 --#|||i ||| j i @ -_ ! [ |x =i - i t i < =i - i;¢ | =i ft _ {x i f Le ¢- 4 1 ia _;_ i 1 Tt 4 =i - \ t 4 -\-a_ 7 6 S \ a t oan l h |0.05.00007.0000TIME(SECONDS)3.000019:57BERN2SKV/7DE'OCT14%1992WED,1.0000 19:57OCT141992BERN2SKV/7DE5.00007.00009.0000WEDTIME(SECONDS),3.00001.0000CASE7DE:NINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN.Wam-BERN2:3:4=0:0:25 B8RAD1;2=2=20:33 COOP1:2=0;:0 SOLD1=0 a SILOS =20.0 MWac.®|SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKY.7DEROTORANGLE:......SOLQOTNA 21 400.00 -_-» 400.0 ROTOR ANCLE:........TESORO #1 #00.00 Kerr x -400.0 ROTOR ANGLE:....,..BRADLEY st 400.00 torr rte +-400.0 ROTOR ANGLE:........COOPER al 400.00 Os cc ceeescccnccce ry "400.0 ROTOR ANGLE:.......BERNICE #4 400.00 __cfr rr -400.0 ROTOR ANGLE:.......BERNICE «#3 400.00 ---s -400.0;+? I |||T ||||8 ° b = + ° k S =_j2 > 7 = | - 3Le_° x -P md .| re r 8=ase.7s APs awe. --St J weNOS cd "te 4 -sy _{s No} N:' +. |°|dx |o CASE7DE:WINTER.KENAI ISLANDEO.BER-SOL-QRTZ 115 OPEN. BERN2:3:4=0;0:25 BRAD1;:2=220;:33 COOP1;:2=0:0 SOLO1=0 |SILOS =20.0 MW Ha SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERN2SKV.7DE FLEC.POWER MW:...,..BRADLEY-2 100.00 me ere 0.0 ELEC.POWER MW:.....BRAOLEY-1 100.00 Xo x 0.0 ELEC.POWER MW:......TESORO-1{ $0.000 wan reense +0.0 ELEC.POWER MW:......COOPER-1 50.000 ereererreeres >m7 ELEC.POWER MW:.....BERNICE-4¥ 50.000 __.--Tr a 0.0 ELEC.POWER MW:.....BERNICE-3 50.000 ---s 0.90 a a a a 0 t ::S i :'osLe\'°.:, ™o14a t m S i :'_j2|;° }:t ¢ 4 s -);+<1 :'6 \|' |°'o =!7 ;,_|s i l x ° ;|eS 't S =':'-_+° }|:' !' :'° '\:*S=°'-}i :'> i]:'2 /x 1 S -f +4 3 \: )'To U¢(/S =' _fe"+--,xt wr” TTT <)2 --m-eK KK 7 ---=°o pm meeec »_° 1 T rn 1 |I ' co)1 |||Ltt ti 19:58OCT141992BERNeSKV/7DEWED,TIME(SECONOS) BEANICE BEANICE SOLDOTNA 0 _ asco qase 9909 so.noric OF 2 Se-0.0 "SS5.0 9904 SD eeCt)a ee Ga Sn |ee 9.0 go-0.0 ;0.0 °°Blo.aoy S882 S|880.0 0.76 °SoD Svs re335 -- °z )9.00.0 75,$0.0 s -3s ols2.9545 a"0.0)0.08°0.6 wo $20.3 ' 0.07 24...p37 SWE =we 3090.0@ssfx-S s ° -0.3 0.0 (;2.3]2 &0.3 0,396 0.0 nny cA6.6)8.8 sheses . 2.187%CEo63 10.976 SKE MILL «Pvc ccc cnc cccescccsccccsccesereosccceccesscescrssaces 8.5=15.2 oY -0.8 ' "31.5 9996 "2.4%0,938 LANMING SKY MILL 0.996 .-20. 36 Ss "10.7 ontz cA "S”=0,938=]9993 -16.4 wi '"in om'.COaloSOLDOTKA"i eo f° TESOAO dlc 0.975 89 ete -15.2 EamedUSPmn a coop LK S/S «0.933 "eY 9931 Sio 518.4 15902 83"t?.=KRSILOF 7 qoOws74oe!SOLOOTNA ah 1 >O°°oSsojo BEAVA TP 0.962 70 L "14.1=nmola 80 BEAVR CR io RNCH PT Th 1.01075eat-91 % ow 013DIAMANGla1.019965Svaes ---------- Lal x -a=2y =13.2)zs 8 4.3 a FRITZ CR BRAD LK19997re?32.4 aS.33.0 3.6 "2 4.4 2) 25.3 1.5 cw -27.1 27.49 as.27.3 1)mor Bos 1.8{{-1.9 O.6]f "<tee i =?8 O-5U1.018 Less<-1.6 "4.4 CASE7EE:WINTER.KENAI ISLANDED.BER-SOL GRTZ 115 OPEN. BERN2:3:420:0:15 8RADI:2=30:33 COOP1:2=0:0 SOLD1=0 mess WED,OCT 14 1992 20:02 KV:569 .$138 .s230 BERNeSKV/7EETIME(SECONDS)CASE7EE:WINTER.KENAI ISLANDED.BER-SOL-ORTZ 115 OPEN. BERN2;3;4=0:0;15 BRAD1:2=30:33 COOP1:2=0;0 SOLO1=0 ™ |SILOS =20.0 MW we SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2@SKV BUS.12/n FILE:CHANNELS\BERN2SKV.7EE ¥FREQUENCY:.,-...TEELAND 230 KV BUS rw 65.000 omens meme me 55.000}& y FREQUENCY:.......BELUGA 138 KV BUS ” 65.000 Xres x 55.000 = x FREQUENCY:MLP PLANT THO 115 KV BUS -65.000 eee +55.000 Q y FREQUENCY:......BRADLEY 138 KV BUS 65.000 Derscccccccsaneces >55.000 Oo y FREQUENCY:....-SOLDOTNA_115 KV BUS 4 65.000 __----oo 55.000 y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 ---_--_----a S5.000 +--#||rT yl T |gis |"8Lej_|2 .oi i:s j 2=se ¢° 4 s =i _|2 i 6 . ° \s =i 7 _|? x ° i 1 : =¢4° 4 1 (8 3 .|=i 1 fT 1 x 8Lei-_> i +nm t ° 4 3 __\pa bei6" 5 }3 =4 _|és |L ||h |< CASE7EE:WINTER.KENAI ISLANDED.BER-SOL-ORTZ 115 OPEN.Wann -BERN2;3;4%=0;0315 BRADIL:2=30:33 COOP1;2=0;0 SOLD1=0 =WwWSILOS=20.0 MW o LJEon]SCENARIO=BERNCSKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/7 q ™ FILE:CHANNELS\BERNGCSKV.7EE ROTOR ANGLE:......SOLDOTNA #1 a 400.00 -r =400.01 Fo ROTOR ANGLE:........TESORO #1 "SF 400.00 Xe x -400.0 in ROTOR ANGLE;.......BRADLEY sf A 400.00 tesco eee +-400.01 ©2AOTOAANGLE:........COOPER «!©uu 400.00 Qe cectcncseocee o -400.0 oO co ROTOR ANGLE:.......BERNICE 4 = 400.00 ----CS -400.0 AOTOA ANGLE:.......BERNICE #3 400.00 -----a -400.0 ¥+ro |||||s S a "Ss 3 -_-o } ° x = =_!2 e q 3 = |°: i S x oi. Nn °Fso ->°(ae)4es q ” uJ a b z ="co oF -_|® y >> 7 So a S =Sy ce Na oe > aN o sy s a ,* ,0 at) oN N 3 = i |° a 4 i °S CASE7EE:WINTER.KENATI ISLANDED.BER-SOL-QRTZ 115 OPEN.Nwn-BERN2;3:4=0:0315 BRAD1;2=30:;33 COOP1;2=0;0 SOLD1=0 a SILOS =20.0 MWhee"SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/ FILE:CHANNELS\BERNGSKV.7EEFLEC.POWER MW:.....SRAOLEY-2 OCT14%199220:14BERN2SKV/7EEWED,100.00 --- .ELEC.POWER MW:.....BRADLEY-! 100.00 x ee es x .ELEC.POWER MW:......TESORO-1! 50.000 oct eoe + .ELEC.POWER MW:......COOPER-1 50.000 oo = .ELEC.POWER MW:.....BERNICE-4 50.000 __--- .ELEC.POWER MW:.....BERNICE-3 50.000 -- |||.I.b>og [| :'' |:\i _ :1 ' \' t \' fox 3 ; bene Py °{ry|:fj t |:1 p 6;t('Q ; =|i ' |:!' °' :|'|:j ' =':|«x ; :.{' |'t ||J ' |:4|4 ||! ---oY ' Sy ' :{'x /' =|coy 'f 4 '(og -w .2.a i>.s”'>Jr x -_--on =re--t--*rE : |||Ji.:4.00006.00003.00005.00007.0000TIME(SECONDS)2.00001.0000Bo OAVE Sv¥S 966BEANICESOLDOTNAoseoe99909969SOLOOTIG |<3 0.0 o3.0 9994 .}p--feG2 2-9,:3.9 ee ee 0.0 o0 0.0 : 0.0 °:ee)See ed0.0 +930 -9Vo.919 .723. 0.8 233 o S35"svs -$3.3 ww ies z 0.01-0.0%°0.8 «=so alo3.985 a )I 74.68 mek:0-0 (S)ae 2gS0.3 40.07 2...g3e7% =-sin $50.0@s43-re =o "4.4 Ho.("3.7 wo "1.4 0.983 90.0 one cA7.4 o.8 aiehes w€l.9 2ten Ce°68 10.930 SKE HILL Jen cca ccc ccc occcocscocssesccccencscscceecorercoscssace 8.5"21.a4 -0.6 . -%.0Ba -40.3 9995 1.4 0,315 LAWING KI MILL "J;"E909 0.983 -22.3 4 D sores "11.9 OAT?CA x ¢.913 =>;9993 -20.8 a a a :soe "P9287 7 1 ba 0.929 zis.felt -21.0 wa et rdwes. T COOP LK:Sle 0.913viv9991SIP-30.8 1,005"33.=986 q Oo en 1.4 nN ees Oo@ oo oo ojo o87 0s KASILOF BEAVA TP 0.937 70 "17.2 r - 80 BEAVA CR ANCH PT oslo:2,001 75 ae a3 OnoOIAMANGSly 1,0069965_cst -6.5 x onfy313.2)%'zo 8 4.4r=) FAITZ CR BAAD LK ?S00 41.8 as 23.0 5.2 ve 6.1 -)23.6 tel =1,"31.4 31.9 as 41.2woSof-1-0|[-1-8 Cor)|med 6.5 1) go 0-5U1.012 1.031<="7.4%73.6 nnn CASE VFE:WINTER.KENAI ISLANDEO.BER-SOL-QATZ 115 OPEN.BERN2:3:4%20:0:3 BRAD1:2242:33 COOP1:220:0 SOLDi=0Fes]WED,OcT 14 1992 20:18 KV:$69 .$138 .s230 CASE7FE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 11S OPEN.Nan-BERN2;3:4=0;0;3 BRAD1;2=42;33 COOP1;2=0;0 SOLDI=0 410.0009.00008.00006.00004.00002.0000SILOS =20.0 MWfimoSCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2S5KV BUS.12/FILE:CHANNELS\BERN2SKV.7FE y FREQUENCY:...,..TEELAND 230 KV BUS 65.000 eee mmm +>55.000 y FREQUENCY:.......BELUGA 138 KV BUS 65.000 Keres ss x S5.000 y FREQUENCY:MLP PLANT TWO 31S KV BUS 65.000 terre +SS.000 y FREQUENCY:......BRAOLEY 138 KV BUS 65.000 Occcccvecenrvrere ry 55.000 2 FREQUENCY:.....SOLOOTNA 115 KV BUS 65.000 --Cr rT 55.000 Y FREQUENCY:.......ZEHNDER 69 KV BUS 65.000 5 SS.900 +-#|Ty i i 9Loi _ ! ! 1 x =i _ i t 4__.!- i 8 ! =iT _! i o¢ f of =t _ 4 | {6 |_| | 1 r |x =i - i t 4 i oO S 1 =\ _ |l |h |7.000020:29BERNeESKV/7FE5.0000TIME(SECONDS)3.00001.0000WED,OCT141992 BERN2:3:4=0:0:3 +SILOS =20.0 MW CASE7FE:WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. BRAD1;2=42;33 COOP1;2=0;0 SOLDI=0 crRee)SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.12/FILE:CHANNELS\BERN2SKV.7FE ROTOR ANGLE:......SOLOOTNA 21 400.00 -_-a -400.0 ROTOR ANCLE:........TESORO a} $00.00 Mere x -400.0 ROTOR ANGLE:..,....BRADLEY =} 400.00 tert etree +- 400.0 ROTOR ANGLE:........COOPER «1! 400.00 Oe ecveosecveccceee ©-400.0 ROTOR ANGLE:.......BERNICE#4 400.00 --7 7 400.0 -AOTOR ANGLE:.......BERNICE «3 400.00 -_-----s -400.0 F *|| [ bs K > = | - b a es ? - [] pantie -- Pe "SSL"A .a oe S45 > oe es -See -tA. * .ae N AY .N =\\ tot :1 '' |||bxi ||10.0009.00006.00006.00004.00002.00005.00007.0000TIME(SECONDS)3.00001.0000WED,OCT14%199220:30BERNeSKV/7FE CASE7FE: BERN2;3;4=0;3033Wann BRAD1:2=42;33 WINTER.KENAI ISLANDED.BER-SOL-QRTZ 115 OPEN. COOP1;2=0;0 SOLO1=0ean]SILOS =20.0 MWMe}SCENARIO=BERN2SKV:FLT/RCLS/FLT/OPEN BERNICE 2SKV BUS.le/ FILE:CHANNELS\BERN2SKV.7FE ELEC.POWER MW:.....BRAOLEY-2 100.00 er re mre 0.0 ELEC.POWER MW:.....BRADLEY-1 100.00 Xerces x 0.0 ELEC,POWER MW:......TESORO-1 50.000 Poccerrsnn +0.0 ELEC.POWER MN:......COOPER-1 50.000 Deer recccercvrecvas o 0.0 ELEC.POWER MW:.....BERNICE-4 50.000 -----0.0 --_ELEC.POWER MW:.....BERNICE-3 50.000 2 0.0 H >||||al 1 |Fy E|s ° :'-_ °' |' °1 °1 ° :a o[s |:8 |+Js : :j '7 -°|4 -- °|'rs) :i] :':°o :{s =:'_/2 x ° |4 }-'-> |'9 :'° :|'tS : 'S «|: \ig -/> .'r>oN _a aLeateCT:| |7 ;|||||A |Lin 20:30OCT141992BERNeSKV/7FEWED,5.00007.0000TIME(SECONDS)3.00004.0000 11/26/32 16:42 NO.026 QC1 STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUE,ENGLEWOOD,COLORADO 80111-2137 FACSIMILE/TELECOPY TRANSMITTAL FORM TELEPHONE NO.303-741-7700 FAX/TELECOPY NO.303-741-7670 VERIFICATION NO,303-741-7156 (USE BALL POINT PEN) TO:O BuUClingqrne caren:O&A TELEPHONE NO: CL.OD,F%te'ABArromoJ:Vole LOCATION:SWEu TELEPHONE NO: , |4540 SHEETPLUS 6 & -o paces pate:J-G-P2 raxrreecorierno:PO7 7G 2 - ACCOUNT COMPANY OFrct Deroy a __1.0.W0.NORIYIAQOLJLJ-L)L)--Lii abla Gje ©}|e ECIAL INSTRUCTIONS TO OPERATOR: MEStA 3E:Oav/of John Lorveadna Aas Sup as a”hol?!lay Cre”a Zriygoly Coaper Lafe as I Sore in Kort &g my yore oeawe,thot we Hip tHe In Ler breUteFHVofCxpord.TAts Will yworouide Oo foeWLestAteGovernorwithoutwolveeriskkeHEA,"Adtachd/on nus he oll fr Lr Case.We will be on site gbhovt noar'onr Hadey.F worldAleetoryttepelowngecletecaefWorksoveferyou,Heoaday -One Unr&é Shutdour-local ocd back bests.Tvesola y --Port A&C Wedhesday-Port O,]/vr2 Old) BS/32 Dosee11/06/52 inte woveNOV=6-82 FRI 114:°836 PTI-WESTERN OF FICE me.es POWER TECHNOLOGIES,INC. FACSIMILE TRANSMISSION one Seraoate Plaza Fax #:(916)783-2086 uite . Tota!Pages:8 Roseville,CA 95678 Tel #:(916)783-3566 TO:John Yale COPIES TO: FROM:John Doudna DATE:November 8,1992 | LgeGba abo SUBJECT:Simulation Of Proposed Kenai Load Rejection TestRRSa I have run a simulation of the Kenai load rejection test which we propose to do next week In order to verify the stability of the Bradley Lake governor controls with the needle integral gain accelerator disabled.Past operation has shown unstable control from Bradley Lake when connected to an isolated system,Our simulations have shown the galn acceleration function to be the prime de-stabilizing factor. The simulation was performed on the full Rallbelt system under typical winter load conditions. The initial conditions are shown by the attached Kenal power flow diagram and Rallbelt generation summary.These conditions may not be Kkdentical to those which will exist,but should be reasonably close.Some small adjustments in Kenal generation may be needed for our test In order to match the 8 MW Kenai export condition used In my simulation. The dynamics simulation was based on the generation conditions shown with Bradley #1 operating and stabilized in the deflector control mode and Bradley #2 operating In the needle (speed)control mode.At time =5 secorids in the simulation breaker 826 was opened, islanding the Kenai.Only natural governor response was allowed on the Kenal units.That is,no AGC control of the governor set-points was used.The simulation was run to time « 300 seconds. The results are shown in the two Sets of attached plots.One set covers a 0-300 seconds 11/26/92 16943 mew ee OO Dk =.e2 Power Technologies,Inc.Page 2 time period,and the other set covers a 0-60 second time period and provides better resolution.Frequency In the Kenal and Anchorage are shown as well as Kenai voltages and Kenal generator electrical power outputs.The second piot in each set shows parameters for each of the Bradley units. For the 8 MW Kenal load rejection,the frequency spikes up to about 60.0 Hz,ramps down to just below 60 Hz within 18 seconds and stabilizes near 60.1 Hz about 1-minute after the load rejection.The Anchorage frequency drops and stabilizes quickly to just below 60 Hz. Kenal voltages at Daves Creek and Sokotna drop about 1.5 percent and 3.0 percent, respectively,after the load rejection.Kenal frequency control Is very stable throughout the 300 seconds of simulation,and there Is no apparent 'fighting'between the two Bradley units. Needle movement on Bradley 2 (needie control unit)Is constrained to reasonable rate limits even though this unit's needie movement Is based on the on-line PID gains. Based on these simulation results,|see no major problems associated with running this test. There are,however,two things which should be done to minimize potential problems. .Disable the overfrequency tripping relays on the Cooper Lake units. .Disable the AGC contro!on all Kenai units Our simulation shows a 0.4 Hz frequency margin below the trip point for the Cooper units. Disabling the overfrequency tripping will assure that the islanded Kenai system will not get hit with a 16 MW load acceptance should the frequency get high enough to pick-up the Cooper tripping relays.Disabfing AGC contro!will allow the governors to respond to frequency according to thelr droop characteristics.Further,it will not introduce any additional potentially unstable control actions,and it will allow us to observe the actual contro!stability of the Bradiey Lake governors with the integra!gain accelerator disabled.This latter concern is the main reason for doing this test. Please advise if you have any questions or want to discuss the results.Also advise If you need me to run any additional simulations. em PrP.o> ihe 6.949 1. Hae -wrteconanawwoerocseeBRAD LK800 28.f af 30,93.45 OS 328) 29.88 .¢40.ican $2.2)fi.033 6,6 NORMAL WINTER LOAD.BRADLEY @ 70MW.COOPER @ 16M. BRADLEY 1 IN DEFLECTOR CONTROL,BRADLEY 2 IN NEEDLE CONTROL. mur.wOv 06 1992 16:82 KV:469 £G338 ,€230__ 11/86/52 loiae ®som meotig «&™/ PTI INTERACTIVE POWER GYSTEN SIMULATOR--PS8/8 NORMAL WINTER LOAD,BRADLEY §TOW.COOPER @ 16MW. BRADLEY 1 IN DEFLECTOR CONTROL,BRADLEY 2 IN NEEDLE CONTROL. TRRATOR SUMMARY: aes 3 $ 691 NAME BSVLT # BELOGAIG13.§& ARLOGASG13.8 BELUGAGG13.8 BELUGA7G13.8 BELUGA8G13.8 RKLUT 266.90 EKLUT 166.90 TERLAND 13.8 GOOP16264.20 PORT W.12.4 ZENORRIG13.8& 2INDRR2G13.8 MN.POLE 13.8 CHENA 12.5 HEALYSVS12.0 BEALY 1613.8 GLDHLSVS13.8 BRADLY1613.8 BRADLY2613.8 PLNTZ 5613.8 FLNT2 6613.8 PLNT2 7613.86 TESOROIGC24.9 SUBSYSTEM TOTALS reyererervrerereesycreaeeavrererererrrererey |aLa)}SONNANWHDDOO898D&6DDDDBDADAD9DDuw 41.9 42.6 73.0 73.0 $4.0 16.0 16.0 0.0 16.0 13.8 4.0 4.8 62.0 18.0 0.0 23.0 6.9 39.0 40.0 24.0 25.0 56.0 4.3 642.5 :twaHNSWOWWSAAAYWHORNThISOAH6.1 QMAX 24.8 'ween THO,NOV 08 1992 16:25 OWIN 712.4 -16.$§ "11.1 "11.1 -15.0 2.2 -2.2 44.0 -9.2 -5.2 -¢.0 -6.06 17.4 -¢.9 -55.6 -7.5 38.0 "19.7 19.7 -8.§ 10.2 24.8 1.5 344.2 VSCRED VACTUAL REM 1.01506 2.0150 1.0180 1.0150 1.0180 1.0000 1.0000 1.00380 1.0300 1.05066 1.0300 1.0270 0.8866 1.03506 1.03006 1.0150 1.8200 1.0009 1.0000 1.0150 1.6200 1.0000 2.0300 2.0150 1.0150 1.0166 2.0150 2.0150 2.90600 1.0000 1.0059 1.0300 2.6500 1.0300 1.0270 0.9860 1.0350 4.6300 4.0250 1.0200 1.0000 2.0000 0.9975 1.6200 2.0000 1.6218 MVABASE® 18 370 402 1064.4 .a+ MOIR AUMOd TWOLIYLOIIZ COfGO FSET 90Adm"IME (318) DUS ee soneOt geoe OE orem gum oe-es wen, om a S.bd¢:J{i1it} TT| feLLLtrh eee | _ |stiae ae Z Be»et jarreecctsccce Pan nnn reeceeeePee wewewewene- @----- ane i "4 . -_- ewe te ew we el ee ee OF{ eS bee dd 5il re HDcameceeceeeeeeOhdeemeemeemenemee ese reewecereeeOOne eee ot” lit ; _ Tf HeeeRAFUFUELe18 LLI1I {4 I SSOVLIOA 2 AONINORG 7 0160 FO6t 90ACM 'I¥s erect ees (ons)paz wees mee se-eer . . . . . aTaEe GenemeeeGoeseeGeenpaneibededlDenies sis fta] - J1Hiietag UO Wh|f ene---2-cseeaee-neee eee on ae 3oy iiY ws aii $;Het 1 ¢4a aa 7 afoecire be > - aad ntoe = = lit g ay HEEE a eS SE Sera ee aeBe)arr*AN beetRB2omomoe "26/se/tt ” SUBLINWaWd 24 ABTCWY 90°60 2661 90ADM'Iwasertct ween (93g)mare seo'es woce it geaditene oul nes.2d.5 LhJoe'eet. 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Vv.Field Tests December 1992 ...... VI.Conclusions .....-.++.+.-e.e VII.Recommendations ........e.. VI Ir e Figures e e e e e e .eo e e e e ° Deflector Test Report Deflector Test Report I.Introduction The Bradley Lake units had periodically been exhibiting unusual operation when the Kenai was islanded with only hydro generation on line,and when transitioning between deflector and speed modes and from condense mode to generate mode when the unit is being controlled by Dispatch.Once in June 1992 and twice in July 1992 the units had undesirable responses when the Kenai was islanded. In each of theses events the Kenai was exporting power to Anchorage. The following operational irregularities were observed: 1.Unstable oscillations occurred when the units were islanded without any other Kenai generation,and left in speed mode. 2.The units have ramped to zero output when transitioning to deflector mode. 3.On at least one occasion when going from deflector to speed mode the unit output has ramped up to full output. 4.The units have ramped to full output when coming out of condense mode to generate mode. To identify the cause of this irregular behavior,a combination of digital simulations and on site testing was performed. II.Problem Analysis The governor mode control is designed for minimal change in unitoutputwhengoverningandgeneratingmodesarechanged.The units should not have responded as reported.A test procedure was developed to see if the unusual actions could be repeated and data gathered to determine a solution.To assist in the analysis,the events of June and July were simulated on PTI's PSSE system modelto:a)Validate the model action versus an actual event,and b)Determine the reasons for the unit operations observed.Thefollowingwereobservedduringthesimulations. A.The overfrequency observed for the Kenai was greater in the digital simulations than that observed during the events. B.An oscillation of frequency occurs when the Kenai is islanded and the units are not placed in deflector mode. Cc.A similar but much less severe oscillation occurs in the Bradley unit left in needle control mode when the other is placed in deflector mode while running isolated. 2 Deflector Test Report Examination of the simulated overfrequency suggested the possibility that the Fuji needle-deflector torque curves used in the simulation may not accurately reflect the actual unit torque when the deflectors are used. Further comparisons of the digital model with the load rejection events performed during unit testing,indicated that there was a difference between the modeled deflector action and that recorded using the DSM.The deflector motion recorded during the load rejection tests had a discontinuity in its travel.It would travel closed at maximum rate,then plateau momentarily,then resume closing at a much slower rate.This plateau is not reflected in the PTI model. A theory which possibly explained the phenomena was the presence of a time lag in the deflector feedback to the governor that caused the governor deflector PID to limit until the assumed deflector 'position could catch up.To determine if the feedback instrumentation was at fault,a linear position transducer wassecuredforcomparisontothepermanentdeflectorpositionfeedbacktransducer. The governor needle PID contains high gains for on-line operation to maximize unit response.These gains are unstable when the units are operated isolated.The simulations indicated that a solution to this oscillation is to place one unit in Deflector mode as soon after the islanding as possible.This transfers the governor fromneedlePIDtodeflectorPIDcontrolwhichisstableinisolated conditions. The needle PID also has a gain acceleration function to further enhance unit response during large speed or setpoint changes.Thisfunctionalsocreatesinstabilityunderisolatedconditionswhen speed or speed setpoint changes become large.One proposedsolutiontotheunstableoperation,Items B and C above,was the elimination of the gain acceleration function of the governor.This function causes the integral gain of the needle PID loop to beincreasedforlargedeviationsbetweenrequireddeflectorand actual deflector position. Test procedures were developed to obtain data or verify each of theaboveconclusions.The original four part procedure was modified during the tests to include five separate tests: 1.Eliminate the gain acceleration function and observe unit response. 2.Observe deflector mode operation on the system,anddeterminewhytheunitrampstozeroandfulloutputon 3 Deflector Test Report occasion auring the transitions.Verify that placing one unit in deflector mode after islanding with an export avoids the frequency oscillations. 3.Observe condense to speed mode transfers and determine why the unit ramps to full output on occasion when coming out of condense mode. 4.Test the deflector feedback for an undesirable time lag. 5.Obtain data to create deflector versus turbine torque curves. IIr.Field Tests November 1992 Field tests were performed November 16 through 18,1992. Additional tests were done on December 17,1992,to verify modifications made to the governor based on the results of the November tests. Test 1 The gain acceleration function was disabled in Unit 2 and the unit restarted in local control.It was difficult and slow to load the unit.The speed setpoint had to be increased significantly pastthedesiredpointtocauseanydetectableunitloadingatall.It was apparent that disabling this function slows unit load control to unacceptable rates.The gain acceleration was enabled and Unit 2 restored to normal operation. Test 2 All governor firmware settings were verified for both units to ensure that there were not changes from the original design. Unit 2 was tested first to determine if the unusual operations could be repeated.No unexpected turbine response was observed when the unit was switched from speed to deflector modes and back in local control.Speed setpoint changes in deflector modes caused the expected change in unit output and stable movement of the deflectors and needles.The unit was switched from speed todeflector,allowed to stabilize and switched back again at powerlevelsof7.5MW,25MW,30MW,and 40MW.No unexpected turbine responses were detected. It was noted that during the switching the power "ratcheted"up.When the unit was operating at 30MW,for example,in speed mode,then was switched to deflector mode the output of the unit went to Deflector Test Report approximately 42MW.(This is to be expected and is explained inthenextsectionofthisreport.) Changes in mode made by the dispatcher were also stable and uneventful. Tests were done by islanding the system with the unit in local and remote control to see if the unusual events of June and July could be recreated.The following are the tests that were done. Test A -Unit 1 and Unit 2 were placed on line at 20MW inremotecontrol,AGC was not enabled.The gain acceleration function was set per the original design.A small export from the Kenai to Anchorage was established.Times given are per CEA SCADA with the Bradley Lake DSM times in parentheses.The DSM clock was not reset from daylight savings time,thus the hour difference recorded. 9:51:37(10:50:56)-The intertie to Anchorage was tripped. Figure 1. 9:52:07 -Unit 2 transferred to Deflector mode by Dispatch SCADA. 10:00 --Unit 2 to frequency base in Dispatch AGC. 10:06 -Intertie to Anchorage was reclosed. No unusual unit operations were observed during this test. Frequency at Bradley Lake varied from 60.7 to 59.6 Hz (Bradley SCADA).The unstable frequency oscillations did not occur. Test B -Bradley units were under Dispatch control with AGC enabled. 10:36:57(11:36:17)-The intertie to Anchorage was opened. Figure 2. The SCADA transfer to deflector was not enabled,no transfer took place.Unit 1 was ramped down by AGC.No unusual operations were observed. Test C -Bradley units were under Dispatch control with AGC enabled.Deflector mode switching was also enabled. 10:50:29(11:49:50)-The intertie to Anchorage was opened. Figure 3. Deflector Test Report 10:50:40 -Unit 1 switched to Deflector mode by Dispatch. Unit 1 immediately ramped to zero output,causing an underfrequency,and resultant underfrequency load shedding when frequency reached 59Hz.Kenai frequency stabilized. Test D -The system was restored and the test repeated. Bradley units were under Dispatch control with AGC enabled. Deflector mode switching was enabled. 11:25(12:24:44)-The intertie to Anchorage was opened. Figure 4. 11:26 (approximate,no time was recorded)-Unit 2 switched to Deflector mode by Dispatch. Unit 2 immediately began to ramp to zero output,the site operator took control of the unit and ramped the setpoint up sufficiently to avoid any underfrequency load shedding. To isolate the cause of the sudden ramping of the setpoint, tests were done with the unit in local and dispatch control with the unit connected to the system.Unit 2 was switched from speed to deflector and back locally in the control room. No unusual operations were observed.The same sequence was repeated with unit control by the Dispatcher.No unusual operations were observed.The sequence was then repeated with AGC enabled in the Dispatchers SCADA system.The following sequence was observed: 15:12 -Unit 2 switched to Deflector mode by Dispatch with AGC enabled.Unit at 30MW.Unit output raised to 40MW by AGC. No unusual operation was observed. 15:14 -Unit output reduced to 20MW by AGC.Output wasincreasedto30MWbyAGC.No unusual actions were observed. Unit switched to Speed mode by dispatch -AGC is enabled. When the unit went to speed mode,the speed setpoint reduced to -5%at a rapid rate,and the unit tripped off on reverse power. The sequence was repeated with AGC control enabled,and the unit responded properly. Further testing of the deflector-speed mode transition was suspended pending consultations with Woodward Governor.Woodward advised that during transition between speed and deflector mode, the deflector setpoint ramp rate is momentarily increased from 1%/second to 100%/second.It appeared possible that an AGC pulse 6 Deflector Test Report might be getting through during the transition period when thehigherramprateisenabled. To test this theory,Unit 2 was placed on line and switched fromspeedtodeflectormode,and a lower pulse introduced at varyingtimesaftertheswitchoverwasinitiated.Two seconds,one second, and immediately were tested.No unusual actions were observed forthetwoandonesecondtests.When the lower pulse was provided immediately after switching to deflector mode,the unit setpointabruptlywentto85%,minimum value,and the output started rampingtozero.The same.happened when switching from deflector to speed mode. Test 3 Discussions with CEA revealed that when the units were operating in condense mode,and system frequency began to drop,the CEA SCADA would send raise pulses to all units in the system,including the Bradley unit in condense mode.This would increase the speed setpoint in the governor such that when the unit came out of condense mode,the setpoint was set for maximum output.Thus,the sudden ramping to full output observed.CEA modified their SCADA to prevent it from sending raise or lower pulses to a unit in condense mode.Because CEA had already corrected the problem at their end,no tests were made in November. Test 4 The position transducer was connected as outlined in the test procedure on Unit 1.A bracket was made and the transducer attached directly to the position indicating arm on the deflector servo.The governor for the unit was placed in manual at theactuatorcabinetandthedeflectorsmovedtothefullopen position.The emergency shutdown switch at the governor cabinet was used to cause the deflectors to stroke closed at maximum rate. DSM scales corresponding to full open and full closed deflector positions were established.Several manual open-close strokes were made on the deflector to establish repeatability of the deflector position signal.The Woodward feedback signal and the temporary transducer signal were both recorded on the DSM. Test 5 Testing for the deflector-torque curves began with establishing the reverse power load of the unit.Recordings of power output at full closed,and 100%open for two and six needles were also made, Figure 5.A full load rejection was done to establish the deflector rate of travel and verify the plateau observed in 7 Deflector Test Report previous tests.Times for these tests are DSM times,corrected for standard time,DSM plot time is in parentheses. 17:04:34(18:04:34)=60MW was rejected on Unit 1.DSM data was taken for analysis.Figure 6. The needle-deflector torque curve tests were done on Unit 1.Data was collected for two and six needles in service,Table 1. 18:38 19:45;Data for two needles was taken. 20:10 =21:28;Data for six needles was taken. Due to high vibration,the six needle 100%output test was aborted at 76%deflector.The unit tripped on high vibration when attempting to raise the deflectors slowly to minimize disturbance to the system. IV.Test Results and Conclusions Test 1 The elimination of the gain acceleration function is not feasible as it makes the unit almost non-responsive.Digital simulations had shown this gain acceleration to be a de-stabilizing influence when two units were operated together islanded on the system,withbothunitsinneedlecontrol,or one unit in deflector control and the other in needle control.The oscillations are smaller and the frequency deviation minimized in the later situation. Woodward Governor has proposed changing the governor from a feedback type,to a feed-forward positioning of the needles.This proposal has been accepted by AEA and the Technical Coordination Subcommittee.These changes will eliminate the oscillations. For the interim period,before the new governor program isimplementedinlatespringof1993,the oscillations when the units are islanded can be prevented by placing one unit in deflector mode.Previous simulations have shown that if one unit is placedindeflectormodewithin12secondsafterislandingtheoscillation is prevented.The tests performed in November verified this as the oscillations did not start for any of the islanding cases. The oscillation of the unit remaining in needle control is not severe enough to cause a system disturbance.It is minor and only effects the wear of the unit due to the constant needle movement. For the interim period,long periods of islanded operation shouldbeavoidedtoreduceturbinewear. 8 Deflector Test Report deflector PID values.This will be studied and new values provided when Woodward revises the governor in early 1993. Woodward believes that the plateau noted is probably due to thedeflectorPIDimplementationinthegovernorsoftware.This willbeexaminedfurtherwhenthegovernorisrevisedin1993.The plateau will be examined to see if it is detrimental to unit orsystemoperation.If it is,it will be modified for acceptableoperation.If it is not and still remains in the revised governor, it will be correctly modeled in the PTI PSSE model. Vv.FPield Tests December 1992 Woodward completed the requested modifications to the governor andsentnewfirmwaretothesite.The new chips were installed and the functions tested on December 17,1992. Initially,all governor firmware settings and tunable parameterswereverifiedforbothunits. The same sequence as was done in Test 2 with the raise or lower pulse applied at the same time as the mode switch did not cause the same setpoint ramping.The units operated properly when controlled locally and from AGC.This was verified for both units. Woodward was requested to prevent acceptance of speed setpoint raise/lower signals when in condense mode.This change was included in new chimps installed on December 17.When the chips were installed the units were placed in condense mode and the operator attempted to raise and lower the speed setpoint.There was not change to the setpoint while the unit was in condense. This test was repeated for the other unit,with similar Satisfactory results. VI.Conclusions The unplanned ramping to full or zero output when switching from speed to deflector modes and back was due to a sneak window in the governor software that allowed speed raise/lower pulses to rapidly increase/decrease the speed setpoint.This has been corrected by changes in the governor firmware. The unplanned ramping to full output when coming out of condense mode was due to increases in the speed setpoint by CEA SCADA when in condense mode.This has been corrected by changes in CEA SCADA and the governor firmware. The differences in overspeed in the simulations as compared to actual events is due to the deflectors being significantly more 10 Deflector Test Report effective than shown by Fuji,and modeled by PTI.This will be corrected in the PTI model and governor. The oscillations observed in the events and the studies are due to the high on-line gains used in speed mode.Operating procedures are in place that minimize system disturbances by placing one unit in deflector mode as soon as possible after they are isolated. VII.Recommendations The following actions and procedures are recommended due to the results of these tests. 1.For the interim period,continue the procedure of placing one Bradley Lake unit in deflector mode as soon as possible,at least within 12 seconds after the become isolated. 2.Minimize deflector operation on the connected system.Whenoperatingindeflectormodeontheconnected_systen,continuously verify unit output to prevent ratcheting to full or zero output. 3.For the interim period,minimize the time operating indeflectormodewiththeotherunitinneedlemodetominimize wear on the turbine. 4.Woodward should modify the governor algorithm to eliminate thehighon-line needle PID gains and gain acceleration function. Note:A purchase order for the changes suggested was placedwithWoodwardGovernoronFebruary1,1993. 5.Do not make any changes to the deflector feedback transducer system.SWEC,PTI,and Woodward should review the deflector control characteristics in the governor to determine if theyshouldbemodified. 6.PTI should modify the PSSE model to match any changes made in the governor and the actual deflector torque characteristics. 11 Table 9. 10. Deflector Test Report VIII.Figures Test A -Kenai Islanding,Only Hydro On Line, Control,Unit 2 to Deflector Mode. Test B -Kenai Islanding,Only Hydro On Line, Control. Test C -Kenai Islanding,Only Hydro On Line, Control;Unit 1 to Deflector Mode. Test D -Kenai Islanding,Only Hydro On Line, Control,Unit 2 to Deflector Mode. Test 5 -Synchronous Condense Power. Test 5 -Unit 1 Power,2 Needles Full Open. Test 5 -Unit 1 Power,6 Needles Full Open. Test 5 -Unit 1 Full Load Rejection. Deflector Feedback,Woodward vs.Test Transducers. Local AGC AGC ACG Deflector Position vs.Power Curves -2 Needle Operation. Deflector Position vs.Power Curves -6 Needle Operation. Deflection Start Curve vs Fuji/Woodward Design Curve. 1 -Deflector vs.Power data. 12 Kenai Load Rejection Frequency &Unit Power Response -10:50:56.00 0.0 j 40,0 ;80,0 ,120.0 ,160.0 61.07 Bradley #1 ¥h 20000. AACS 60.57 Bradley #2 15000. § <= 10000.60.0 )Frequency 5000. 57 ..*9 (Power scales at right are in kW) 0.0 40.0 80.0 120.0 160.0 Seconds 1.Test A -Kenai Islanding nly Hydro On Line,Local Control,Unit 2 to Deflect Mode. Kenai Load Rejection Frequency &Unit Power Response -11:36:17.00 61. 60.Herz59. 60. 0.0 40,0 80,0 160.0 Bradley #1 Bradley #2 20000. 15000. 10000. 5000. (Power scales at right are in kW) 0.0 40.0 80.0 120.0 160.0 _ Seconds _ 2.Test B -Kenai Islanding,Only Hydro On Line,AGC Control. Kenai Load Rejection Frequency &Unit Power Response -11:49:50.00 - 0.0 \40,0 ,80,0 F 120.0 ,160.0 ero"Bradley#2 -20000. ' 60.57 r 15000. 60.0 + g -10000. je 2 Frequency 59.57 -5000. Bradley#1 s 0. §9.07 (Power scales at nght are in kW) 0.0 40.0 80.0 120.0 160.0 Seconds 3.Test C -Kenai Islan ,Only Hydro On Line,AGCOControl,Unit 1 to Defl r Mode. Kenai Load Rejection Frequency &Unit Power Response -12:24:44.00 | 61. 60. 60. 60.Hertz60. 60. 59. 59. 0.0 ;40,0 ;80,0 120.0 160.0 04 .-Bradley #1 -20000. 6 4 1 Bradley #2 P 15000. 4 -10000. 0 }Frequency 8--5000. '6 (Power scales al right are in kW) 0.0 40.0 80.0 120.0 160.0. ee ee ce eee Seconds ee cece nee ee ee eater 4.Test D -Kenai Islanding,Only Hydro On Line,ACG Control,Unit 2 to Deflector Mode. Bradley #1 Reverse Power In Synchronous Condense Mode 1000000.07 800000.07 Watts600000.07 400000.07 200000.07 Per Unit Of 2-Needle Full Power =-0.03240138 Median Power Level =712261.47649027 Mean Power Level =708522.91707634 Per Unit Of 6-Needle Full Power =-0.01106609 ¥¥ 0.0 100.0 200.0 Ls uu 300.0 400.0 Samples 5a.Test 5 -Synchronov 7tondense Power. 2-Needle Full Power Output From Bradiey#1 -21600000.07 i) -21800000.07 ||| q | = -22000000.0° -22200000.0- Mean Power Level =-2.18679257E+007 -22400000.0 7 ;:,:;: 0.0 100.0 200.0 300.0 400.0 500.0 }#£600.0 Le Samples 5b.Test 5 -Unit 1 Power,2 Needles Full Open. 6-Needle Full Power Output From Bradley #1 -63500000.07 -64000000.07 |3 | -64500000.07 . Mean Power Level =-6.40272625E+007 v T L v ¥ 0.0 100.0 200.90 300.0 400.0 500.0Samples 600.0 5c.Test 5 -Unit 1 Powr 6 Needles Full Open. 0.0 2.0 4.0 6.0 8.0 10,0 12,0 14,0 16,0 18,0 65.07 Frequency 64.07 63.0- 62.07 61.07 Deflector Position (relative -no established scale) 60.07 59.0 ¥u t T T T v v 0.0 2.0 4.0 6.90 8.0 10.0 12.0 14.0 16.0 18.0 6.Test 5 -Unit 1 Full Load Rejection. Deflector Movement For Emergency Shutdown (Both Transducers) 1.6 2.0 2.4 2.8 3.2 3.6 4.0 4.4 ThK )Wopdward Transducer (scales jon right)6.0 NA ke JN 3 /\ann'(scales on leff)\ 2.0 \NaeMKPow 1.6 2.0 2.4 2.8 3.2 3.6 4.0 4 Seconds 7.Deflector Feedback,Woc ard vs.Test Transducers. We:Sanitized Deflector Curves For 2-Needle Operation 0.90 1 20,0 '40,0 ,60,0 F 80,0 . 1.07 100%Needle 80%Needle 0.87 t 0.67 40%Needle bz a B@ 0.4- &a 20%Needle 10%Needle 0.0- orm perme me ee T T 7 Li ig v T TOT ernare 0.0 20.0 40.0 60.0 80.0 eee tutte tee tenweuues on sues osm 1 Deflector Pos ee eeeeee cee 8.Deflector Position vs.Power Curves -2 Needle Operation. |W6:Sanitized Deflector Curves For 6-Needle Operation rTq0.0 ,20,0 ;40,0 \60,0,80,0 . 1.07 100%Needle 80%Needle 0.87 t 0.67 40%Needle bz a 8B 0.47> 3 Qn 20%Needle 0.27 /Jf10%Needle 0.0 _Z/ i Sirens T u T T T ¥Tv T 0.0 20.0 40.0 60.0 80.0 %Deflector Pos Deflector Position vs.Pe *r Curves -6 Needle Operation. W 10:Actual Deflection Start vs Woodward Deflector Positioning Points 0.0 0.1 O.2 0.3 0.4 O15 90. 1.07 0.87 0.67 SQn 3 z 0.47 0.2 T T T v t T T T T 0.90.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 Deflector Pos _ee _. Deflection Start Curve vs Fuji/Woodward Design Curve.10. 'able Uf Collected Del 2-Needle Operation or Position &Power Data 10%Needle 20%Needle 40%Needle 80%Needle 100%Needle %Deflector Per Unit %Deflector Per Unit %Deflector Per Unit %Deflector Per Unit %Deflector Per Unit.Position Power Position Power Position Power Position Power Position Power 5.0 -0.0356 5.0 -0.0361 14.9 -0.0380 50.0 0.0163 59.9 0.0961 9.3 -0.0359 9.9 -0.0370 19.6 -0.0386 54.8 0.0816 64.4 0.2613 14.8 -0.0290 15.1 -0.0363 24.6 -0.0395 60.0 0.2665 70.0 0.4815 19.7 -0,.0057 20.2 -0.0325 29.7 -0,0376 64.9 0.4432 75.0 0.6686 24.6 0.0208 25.1 -0.0014 35.1 -0.0108 69.5 0.6043 719.7 0.8446 29.7 0.0726 29.5 0.0441 40.2 0.0833 19.9 0.8643 84.6 0.9780 61.5 0.1144 35.1 0.1164 45.1 0.1964 69.4 0.8764 89.2 1.0010 39.6 0.1947 49.7 0.3157 100.0 0.8763 94.8 1.0020 45.0 0.2435 55.1 0.4298 100.0 1.0000 49.17 0.2513 60.2 0.4881 54.6 0.2513 64.8 0.4977 59.6 0.2512 19,7 0.4963 89.8 0.4923 100.0 0.4966 6-Needle Operation 10%Needle 20%Needle 40%Needle 80%Needle 100%Needle &Deflector Per Unit %Deflector Per Unit %Deflector Per Unit &Deflector Per Unit &Deflector Per Unit Position Power Position Power Position Power Position Power Position Power 14.3 -0.0061 24.2 0.0060 38.7 0.0329 62.4 0.0834 18.3 0.2696 19.3 0.0073 30.2 0.0333 44.1 0.0493 66.6 0.1768 78.9 0.3642 25.0 0.0223 34.6 0.0515 49.6 0.1423 72.8 0.3219 82.3 0.4503 29.2 0.0687 39.3 0.14961 55.0 0.2794 77,5 0.4716 64.3 0.5438 89.0 0.1216 44.9 0.2610 60.0 0.5023 80.1 0.6487 86.5 0.9511 50.1 0.2731 62.5 0.5243 61.86 0.8824 87.6 0.9886 59.7 0.275!64.7 0.5311 83.2 0.8903 91.2 0.9999 100.0 0.5306 99.9 0.8938 96.3 1.0006 100.0 O 1.0000 POWER TECHNOLOGIES,INC. FACSIMILE TRANSMISSION One Sierragate Plaza Suite 340B Total Pages:23 Roseville,CA 95678 _-.Fax #:(916)783-2086 Tel #:(916)783-3566 TO :Dave Burlingame Steve Haagenson Larry Hembree FROM:John Doudna DATE:July 9,1992 SUBJECT:Kenai UF Load Shedding This memo conveys the results of our examination of the Kenai underfrequency (UF)load shedding requirements.In conducting this task,we have encountered several problems when simulating Kenai islanding under high import/minimum generation conditions.We have also had difficulty identifying a UF load shedding scheme for the Kenai which will provide 'ideal'frequency response for different levels of Kenai generation and import. The initial plan was to conduct this examination for a winter peak load condition with only the Cooper Lake generation on-line at 16 MW.However,we found that following islanding,short-circuit levels on the Kenai system dropped so low that we could not achieve a convergent solution in our dynamic simulations.We then switched to using one Bradley Lake unit at 16 MW.This gave the same power balance for the Kenai and higher post-islanding short-circuit levels.However,we still sporadically encountered some solution convergence problems due to the simplified SVC model we are currently using for Soldotna.We circumvented this problem by taking off the Soldoma SVC and using the Soldoma CT as a 'dummy'synchronous condenser.In the dynamic simulations,the Soldotna CT was given an inertia of zero and the governor was disabled so as not to effect the frequency response of the system.These changes provided the required var support for the initial steady-state loadflow conditions,and it allowed us to achieve convergent solutions in the post-islanding dynamic simulations when the Kenai short- circuit levels were diminished to low levels.i Power Technologies,Inc.Page 2 Recent simulations of islanded Kenai system operation with only Bradley Lake on-line (i.e.,no CTs),have shown that the Bradley governor provide unstable frequency control response when left in the needle control (normal)operating mode.Switching one Bradley unit to the deflector control mode has been shown to provide stable frequency response under islanded Kenai conditions.Toggling one Bradley Lake unit to deflector control has been recommended following Kenai islanding situations. We have also observed from our preliminary Kenai load shedding simulations that AGC control on Bradley,during underfrequency conditions with the Kenai islanded,over-drives the governor speed reference.This results in steady-state,post-islanding frequencies being high.This problem is exaggerated if Bradley is toggled to the deflector controlled mode and AGC control is applied to Bradley during underfrequency conditions.Under such situations,the AGC acts as an unstable control loop.This needs to be avoided. Thus,all simulations run as part of the Kenai underfrequency load shedding study task have used the following assumptions: °One Bradley unit is toggled to the deflector control mode following islanding of the Kenai system °AGC control over Bradley is suspended for Kenai islanding events The results from our examination are attached in the form of dynamic simulation frequency plots,and they are discussed below. The starting point for Kenai UF load shedding evaluation was the 10/10/10%,3-stage load shedding allocation previously identified for the interconnected Railbelt system and reported in our April 29 letter report.Through an iterative process,we arrived at a total load shedding level for the Kenai system with only 16 MW of hydro generation on-line and importing 62 MW at Daves Creek.We also tested various shed frequencies for the third stage as well as the allocation of shedding among the three stages. The final results are shown in Plot 1.This shows frequency response for shedding 75% of the Kenai load in a 10/25/40%allocation.The frequency dips to a low of 54.8 Hz about 6 seconds following islanding,rebounds to 63 Hz over the next 16 seconds,and then settles to about 60.8 Hz.Due the rapid frequency decay for this condition,it was found that allocation of load shedding among the three stages made no difference in the Power Technologies,Inc.Page 3 system frequency response.Further,it did not affect the minimum frequency point. Shedding less that 75%of the Kenai load did not allow the frequency to recover. Shedding more than 75%of the Kenai load (i.e.,80%)limited the frequency dip to about 56.4 Hz.However,the frequency then recovered very rapidly to a high of 63.3 Hz and settled at 61.0 Hz.Thus,the 75%load shedding response shown in Plot 1 provides about the best frequency performance which can be expected given the hydro-only generation condition. This frequency performance does,however,raise some concerns given the current under/over frequency relays now used on Kenai generation.First,the Bradley units are presently set to trip at an underfrequency of 55.0 Hz.This is a limit (somewhat arbitrary) established to coordinate with other Railbelt generator UF relays.However,there is nothing in the design of the Bradley turbine-generator equipment which would prevent operation at lower frequencies.Second,Cooper Lake is presently equipped with overfrequency protection set to trip the unit at 61 Hz.Thus after load shedding on an islanded Kenai system,frequency recovery to 61 Hz or above would result in the tripping of the Cooper units if they were on-line.This would compound the resource deficiency in the Kenai and again drive frequencies down. The above load shedding schedule was tested on several 'what if?generation scenarios to verify system frequency performance.The first 'what if'scenario tested maintained the same level of Kenai generation and import as used in the Plot 1 case,but Bernice Lake #2 was placed on-line at 3 MW with 13 MW carried by Bradley.The results are shown in Plot 2.As can be seen,the presence of the CT generation limits the frequency dip to about 57.8 Hz.All three levels of load shedding still occur,but frequency recovers faster and only rebounds to about 61.6 Hz before settling at 60.6 Hz.It was also found that the allocation of load shedding did not make any difference in frequency performance even with the CT on-line.This response indicates that the 75%load shedding remains viable under high Kenai import,low generation conditions when a CT is present. Plot 3 shows a second 'what if'scenario to verify frequency performance with the above load shedding magnitude and allocation.This plot assumes Bradley Lake is the only Kenai generation,operating at 30 MW,and that the Kenai import is 47 MW.For this situation,islanding of the Kenai results in rapid frequency decay and the pick-up of all three stages of load shedding.However,after the third stage of load shedding,the frequency decay is abruptly arrested at 58 Hz,and then rapidly recovers to about 62.3 Hz. Power Technologies,Inc.Page 4 It stabilizes around 60.8 Hz.Thus,75%UF load shedding in this situation will arrest frequency decay on the Kenai system,but it does obviously over shed. Plots 4 and 5 are an extension of the 30 MW Kenai generation,47 MW Kenai import conditions,but Bernice Lake #2 is assumed to be on-line at 3 MW.In Plot 4,it can be seen that with the CT on-line and with a 10/25/40%allocation of the load shedding,all three stages trip.It can also be seen that the CT limits the minimum frequency to about 58.1 Hz;only a 0.1 Hz improvement over the 30 MW,hydro-only condition.Plot 4 again shows that over shedding occurs on the Kenai system. In Plot 5,the load shedding allocation between the second and third stage was changed, providing 50%load shedding in the first two stages versus the 35%used in the Plot 4 simulation.This change along with the Bernice Lake #2 CT is sufficient to limit Kenai load shedding to two stages (i.e.,50%of the total Kenai load).Moreover,it limits the frequency rebound to about 60.8 Hz before settling to 60.3 Hz.Further,this case does assume that the third stage of Kenai load will not shed until 58.2 Hz.This is the frequency point presently used in the Kenai for the third stage of load shedding. However,it is below the 58.4 Hz third stage point previously identified for the interconnected Railbelt system.This is the first case where the allocation of load shedding among the steps made any significant difference. Plots 6 through 9 show Kenai frequency performance following islanding with 40 MW of hydro generation on-line and a 37 MW import at Daves Creek.Plot 6 shows the response when the 10/25/40%load shedding allocation is used.All three stages shed under this conditions,but the frequency dip is limited to about 58.1 Hz.The frequency recovers rapidly to 63 Hz and settles at 61.1 Hz.Although the frequency decay caused by islanding under the 37 MW import condition is arrested,significant over shedding of load in the Kenai results for this situation. Plots 7 through 9 show the result of re-allocating load shedding.All three plots show the results when 50%of the Kenai load is shed in the first two stages.The simulations differ only by the amount of load shed in the first and second stage.These cases do again assume,however,that the third stage will not shed until the frequency drops to 58.2 Hz. In all three simulations,shedding 50%of the Kenai load in the first two stages prevents shedding the third stage.However,the Kenai frequency remains only marginally above the 58.2 Hz level.The allocation of load shedding between the first and second stages does not significantly alter the system response.These cases do,however,indicate that Power Technologies,Inc.Page 5 shedding a larger percentage of load in the first two stages can reduce Kenai load shedding for moderate Kenai import conditions. Plots 10 and 11 show Kenai frequency response for a 40 MW Kenai generation,37 MW Kenai import condition,but with the Bernice Lake #2 CT on-line at 3 MW.Plot 10 shows that with the 10/40/25%load shedding allocation,the Kenai frequency remains above the third stage trip point,and recovers abruptly after the second stage sheds.The frequency rebounds to about 61.2 Hz in 20 seconds and then settles to near 60.7 Hz. Thus,this case indicates over shedding of Kenai load for this generation condition. Plot 11 was conducted to test the 10/25/40%load shedding allocation used in the preceding simulations.It shows that this load shedding allocation is viable for this Kenai generation/import situation when the CT is on-line.The Kenai frequency remains above the third stage trip point,and the frequency rebounds to 61.1 Hz in about 35 seconds before settling to about 60.4 Hz.Compared to the 40 MW hydro-only generation condition shown in Plots 7 to 9,the allocation of load shedding within the first two stages can be reduced when a CT is on-line. Similar analysis were also run for a SO MW Kenai generation,27 MW Kenai import condition.The results are shown in Plots 12 through 15.Plots 12 through 14 show the frequency response for a hydro-only generation condition with 35%of the Kenai load targeted for shedding in the first two stages.These three case vary only by the allocation of the 35%of UF load shedding between the first and second stage.In these cases,the frequency decay caused by islanding of the Kenai is arrested abruptly following the second stage of load shedding.The frequency dips to about 58.4 Hz (above the third stage pick-up point of 58.2 Hz),and rebounds to about 61.8 Hz before settling at 60.2 Hz. The frequency response is not sensitive to the allocation of load shedding between the first and second stages. Plot 15 represents the frequency response with the 50 MW Kenai generation schedule,but the Bernice Lake #2 CT is on-line carrying 3 MW.The initial frequency dip is reduced by the CT,but the CT does not prevent the second stage of load shedding from operating. Frequency recovery is much faster than in the hydro-only generation scenario,and the rebound frequency overshoot is much smaller than for the hydro-only condition. However,the frequency stabilizes at the same point;60.2 Hz. Power Technologies,Inc.Page 6 Conclusions Survival of an islanded Kenai system under heavy import,hydro-only generation conditions will require the following items to be implemented: °Lower Bradley's UF trip point to 54 Hz or lower.This relay could be eliminated entirely and allow the volts per hertz relay at Bradley to protect the units. °Supervise Cooper Lake's OF tripping such that it will not trip on overfrequency if the frequency hasbeen below 60 Hz (say 59.5 Hz)within a short period prior to reaching the 61 Hz level.This supervision logic should then be reset after the frequency has stabilized near 60 Hz for a sufficient period of time (say 20 seconds). °Lower the UF trip point for Bernice Lake #3 and #4 from 58.2 Hz to 57.0 Hz. This will make the trip point of these units the same as Bernice Lake #2. These changes will allow Bradley to ride through low frequency situations except those which are compounded by very low voltage and which cause Bradley's volts per hertz relay to trip the units.They will preserve the overfrequency control provided by the tripping of Cooper Lake for Kenai islanding under high export conditions,but without compounding Kenai resource deficiency problems while rebounding from an underfrequency situation.When CT generation is on-line in the Kenai,it will allow all of the Bernice Lake CTs to ride through the frequency dip which can occur prior to action of the third stage of UF load shedding.This will provide a consistent,minimum Kenai frequency limit when any of the Bernice Lake CTs are on-line. Given the requirement that the Kenai be able to survive islanding under winter load conditions with as little as 16 MW of hydro generation on-line,75%of the Kenai's load will need to be targeted for underfrequency shedding.The allocation of this load shedding among three stages is not highly critical to the islanded Kenai's frequency recovery. Moreover,no single allocation can provide optimal performance under all Kenai generation/import conditions. The results of this study suggest two possible UF load shedding schedules for the Kenai as shown in the following table.Both schedules can result in over shedding given specific Kenai generation schedules.However,both schedules can likewise provide appropriate levels of load shedding in the Kenai given certain generation dispatches. Power Technologies,Inc.Page 7 Pick-Up Kenai UF Load Shedding Schedule Frequency Option #1 Option #2 59.0 Hz 10%10% 58.7 Hz 25%40% 58.2 Hz 40%25% However there are other considerations,not examined in this task,which will need to be considered in selecting the load shedding for the Kenai.One important consideration is that during low frequency,high Kenai export,interconnected system operating conditions, the Kenai should not shed large amounts of load.Shedding large amounts of load in the Kenai under such conditions could cause the Kenai system to go out-of-step.Although the Kenai system would likely survive,the impact on the remainder of the Railbelt would be detrimental. This factor will be considered in the remaining study of the interconnected Railbelt system.However,it is possible that this study will show that both UF load shedding schedules noted above are not viable.Thus,based on interconnected system operation under high Kenai export conditions,the requirement may be to lump the majority of Kenai load shedding into the third stage,and minimize first and second stage UF load shedding. This,however,will nearly guarantee that excessive load shedding will occur in the Kenai following islanding under moderate import conditions. Other alternatives for the Kenai may be feasible.These have not been considered,and their consideration exceeds the work allocated for the remainder of the load shedding study.Some of the alternatives,however,which could be considered are: °Installation of rate-of-change frequency relays which allow tripping large amounts of Kenai load only for fast rates of frequency decay.This option could involve significant costs. °Use lower second and third stage frequency points on the existing Kenai relays. This would limit load shedding in the Kenai for interconnected,low frequency conditions (i.e.,force the Anchorage &Fairbanks areas to do the majority of the majority of the required load shedding for interconnected system conditions),but Power Technologies,Inc.Page 8 it would also likely result in lower frequencies occurring in the Kenai following islanding under import conditions. °Establish higher,minimum generation levels (e.g.,30 MW)for the Kenai.This would reduce the total amount of Kenai load which would need to be targeted for shedding and thereby reduce the first and second stage shedding requirements. This consideration would be most critical when operating under a hydro-only generation situation. °Use a combination of the above options. Developing a UF load shedding scheme for the Kenai will involve the consideration of many 'trade-offs'.The current objectives,expectations and physical limits do not allow much flexibility in developing a UF load shedding scheme which will respond correctly and as desired under all foreseeable operating situations. After you have reviewed this transmittal,please advise if you have any questions or if you would like to discuss it further. NORMAL WINTER LOAD;BRADLEY AT 16MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW ifKENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; |}UF LS:1=#10%,2=25%,3=40%;AGC IS OFFFILE:DC2540AA.CHN SOLDOTNA FREQUENCY (HZ) 64.000 3-----9 54.000 |||||60.00048.00036.000-0002412.00011*D1330.00042.00054.000TIME(SEC)18.0006.0000JUL081992KENAIISLAWED, NORMAL WINTER LOAD;BRADLEY AT 13MW;BERNICE 2 AT 3MW;wr DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW ronan KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; ee)UF LS:1=10%,2=25%,3=40%;AGC IS OFF FILE:DC1025-E.CHN SOLDOTNA FREQUENCY (HZ) 64.000 54.000 rT Td 60.00048.00036.00024.00012.0000.013:0330.00042.00054.000WEDTIME(SEC)'16.0006.0000JUL081992KENAIISLANDED NORMAL WINTER LOAD;BRADLEY AT 30MW;nw DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMWPomERKENAIISLANDEDAT1SEC;DEFLECTOR CONTROL; es]UF LS:1=#10%,2=25%,3=40%;AGC IS OFF FILE:DC1025B1.CHN ©) "_ __SOLDOTNA FREQUENCY (HZ) 64.000 S a 54.000 |||g =_18 = |4: r-e -8 3 325"DJUL08199213KENAIISLAIWED,TIME(SEC) DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW |KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL;fi NORMAL WINTER LOAD;BRADLEY AT 27MW;BERNICE 2 AT 3MW; UF LS:1=10%,2=25%,3=40%;AGC IS OFF FILE:DC1025-B.CHN SOLDOTNA FREQUENCY (HZ) 64 -000__54.000 ||||||60.00046.00036.00024.00012.00030.00042.00054.000TIME(SEC)18.0006.0000:0513JUL081992KENAIISLANDEDWED, idNORMAL WINTER LOAD;BRADLEY AT 27MW;BERNICE 2 AT 3MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; UF LS:1=10%,2=40%,3=25%;AGC IS OFF FILE:DC1040-B.CHN 64.000 SOLDOTNA FREQUENCY (HZ) 54.000 rT 7d |60.00048.00036.00024.00012.00042.00054.00030.000TIME(SEC)18.0006.0000:10DJUL0819921%KENAIISLANWED, Wn NORMAL WINTER LOAD;BRADLEY AT 40MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; |if fe UF LS:1=10%,2=25%,3=40%;AGC IS OFF FILE:DC1025-C.CHN S) SOLDOTNA FREQUENCY (HZ) 64.000 ee 54.000 60.000468.00036.00024.00012.000.42.00054.00030.000WED,TIME(SEC)18.0006.000013:13JUL081992KENAIISLANDED NORMAL WINTER LOAD;BRADLEY AT 40MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL;ii1 UF LS:1=10%,2=40%,3=25%;AGC IS OFF FILE:DC1040CA.CHN SOLDOTNA FREQUENCY (HZ) 64.000 8 54.000 ||||||60.00048.00036.000-0002412.00030.00042.00054.000TIME(SEC)18.0006.0000216"=DJUL08199213KENAIISLAN™WED, NORMAL WINTER LOAD;BRADLEY AT 40MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; UF LS:1=5%,2=45%,3=25%;AGC IS OFF FILE:DC545CA.CHN -_-_SOLDOTNA FREQUENCY (HZ)1413KENAIISLANDEDJUL081992WED,64.000 &8 54.000 ||q |||60.00024.00036.00048.00018.00030.00042.00054.000TIME(SEC)12.0006.0000 iliNORMAL WINTER LOAD;BRADLEY AT 40MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; UF LS:1#15%,2=35%,3=25%;AGC IS OFF FILE:DC1535CA.CHN SOLDOTNA FREQUENCY (HZ) 64 -900 @54.000 ||||to |60.00048.00036.00024.00012.00017*D1330.00042.000§4.000WEDTIME(SEC)'18.0006.0000JUL081992KENAIISLAP |DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL;I |)NORMAL WINTER LOAD;BRADLEY AT 37MW;BERNICE 2 AT 3MW; Ecmecucares,|}UF LS:1=10%,2=40%,3=25%;AGC IS OFF FILE:DC1040-F .CHN SOLDOTNA FREQUENCY (HZ) 64.000 54.000 |ij |60.00048.00036.000-0002412.000.054.00013:08WED,30.00042.000TIME(SEC)18.0006.0000JUL081992KENAIISLANDED NORMAL WINTER LOAD;BRADLEY AT 37MW;BERNICE 2 AT 3MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL;60.00048.00036.00024.000me]UF LS:1=10%,2=25%,3=40%;AGC IS OFF FILE:DC1025-F.CHN "_ _SOLDOTNA FREQUENCY (HZ) 64.000 8 54.000 ||||||12.0000.006"D1330.00042.00054.000TIME(SEC)18.0006.0000JUL081992KENAIISLAWWED, [1 |NORMAL WINTER LOAD;BRADLEY AT SOMW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW m7]KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; is :2=25%,3=40%;AGC IS OFF FILE:DC1025-D.CHN :SOLDOTNA FREQUENCY (HZ) 64.000 &54.000 |g 2 f=] _-S S 1s S 0.02013.54.00030.00042.000WED,TIME(SEC)18.0006.0000JUL081992KENAIISLANDED NORMAL WINTER LOAD;BRADLEY AT S5OMW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMWiKENAIISLANDEDAT1SEC;DEFLECTOR CONTROL; |UF LS:1*15%,2=20%,3=40%;AGC IS OFF FILE:DC1520-D.CHN SOLDOTNA FREQUENCY (HZ) 64.000 54.000 60.00048.00036.0000002412.000-030.00042.00054.000WEDTIME(SEC),16.0006.000013:21JUL081992KENAIISLA?r*D DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; [)NORMAL WINTER LOAD;BRADLEY AT 50MW; scmectooras J UF LS:1=5%,2=30%,3=40%;AGC IS OFF FILE:DC530-D.CHN SOLDOTNA_FREQUENCY (HZ) -000 54.000 60.00048.00036.000.0002412.00030.00042.00054.000WEDTIME(SEC)'18.0006.000013:18JUL081992KENAIISLANDED NN ann- Te © NORMAL WINTER LOAD;BRADLEY AT 47MW;BERNICE 2 AT 3MW; DAVES CREEK SVC IN SERVICE;SOLDOTNA GEN AT OMW KENAI ISLANDED AT 1 SEC;DEFLECTOR CONTROL; J UF LS:1=10%,2=25%,340%;AGC IS OFF FILE:DC1025-G.CHN SOLDOTNA FREQUENCY (HZ) 64.000 & =?)54.000 rT 60.00048.00036.000.0002412.0000.007'D1330.00042.00054.000WEDTIME(SEC)'18.0006.0000JUL081992KENAIISLAN STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUEuNENGLEWOOD,COLORADO 80111 -2137 ADDRESS ALL CORRESPONDENCE TO P.O.BOX 5406,DENVER,COLORADO 80217-5406 W.U.TWX:910 935-0108 TELEPHONE:303 741-7700 FAX:O3-741-7670 W.U.TELEX:45-4401 RCA TELEX:289251 303-741-7671 BOSTON MA NEW YORK NY CHATTANOOGA TN Oan RIDGE TN CHERRY MILL.AS PORTLAND ME CHICAGO (tL PORTLANG OR OALLAS TX RICHLAND WA OECATUR AL RICHMOND VA CENVER CO PLEASANTON CA PT LAUDERDALE.Fu TAMPA FL HOUSTON TX WASHINGTON OC November 13,1992 Mr.David Burlingame Chugach Electric Association 5601 Minnesota Drive Anchorage,AK 99519 TECHNICAL COORDINATION SUBCOMMITTEE MEETING BRADLEY LAKE HYDROELECTRIC PROJECT The next meeting of the Technical Coordination Subcommittee (TCS)will be held at the offices of the Alaska Energy Authority beginning 9:00 a.m.,Thursday,November 19,1992. On behalf of the Energy Authority,enclosed is the agenda for the meeting and a memo from Mr.Ted Critikos to Mr.D.Eberle dated November 13,1992. Under seperate cover the minutes of October 8,1992 TCS Meeting will be transmitted by Chugach Electric Associtation.Please notify the appropriate individuals within your organization of the upcoming meeting and distribute the advanced materials accordingly. Wedel -[qn TH Cut hosTheodoreCritikos Project Manager Enclosure TC/MWG/swg DO1095.wet.wetBL007 i¥8y ©STONE &WEBSTER«+yee AGENDA BRADLEY LAKE HYDROELECTRIC PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MEETING Held at the Offices of Alaska Energy Authority 701 East Tudor Road Anchorage,Alaska November 19,1992 9:00 a.m. I.APPROVAL OF OCTOBER 8,1992 MEETING MINUTES it.APPROVAL/MODIFICATION OF AGENDA il.OLD BUSINESS A.SVC Project -Status B.SVC Testing,Plan and Utility Costs -Status C.Bradiey Lake Operation -Status D.DECnet -Status E.SVC Simulator Studies Comparisons -Status F.Bradley Lake Oscillations and Islanding -Status G.Bradley Lake Deflector Mode/Additional Turbine Tests -Status IV.NEW BUSINESS A,Woodward Governor Control Modification 001095.wpt/BLOO7 STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUEAENGLEWOOD,COLORADO 80111 -2137 ADDRESS ALL CORRESPONDENCE TO PO.BOX 5406,DENVER.COLORADO 80217-5406 wu Twx 910 935-0105 TELEPHONE:303 741-7700 FAX,303.741.7670 wu TELEX:45-4401 RCA TELEX.28925)3O3-741.7671 .seston we,garmeee Ta ounven co”sucasanTonCA voueton ate Lis wasuinGTON ec Mr.OD.R.Eberle November 13,1992 Project Manager Alaska Energy Authority J.O.No.19239.23 701 East Tudor Rd.WP 26C Anchorage,AK 99503 SWEC/AEA/2927 KENAI POWER SYSTEM SIMULATION RESULTS STATIC VAR COMPENSATOR SYSTEM BRADLEY LAKE HYDROELECTRIC PROJECT At the request of the Technical Coordination Subcommittee (TCS),Power Technologies,Inc. has reviewed the simulation studies performed by ABB Power Systems,Inc.Attached is a Letter Report on ABB/PTI Study Comparisons,prepared by PTI which outlines each ABB study case and how the PTI results can be compared to the ABB results.PT!concludes that the ABB results are consistent with the PTI results.Stone &Webster Engineering Corp.(SWEC) concurs with the PTI conclusions and reaffirms the conclusions we presented to the TCS on October 8,1992 in our letter SWEC/AEA/2916. To support our conclusions,SWEC and PT!have summarized all previous reports and correspondence relating to Bradley Lake including reference to other projects that effect or relate to the operation of Bradley Lake.This summary,which is attached,does not include work relating to the interim operation of Bradley Lake. The conclusions and recommendation of past study results are consistent among SWEC,SCI, PTI and ABB.With SVC's installed,the Kenai system consistently has a normal rating of 75 MW export at Daves Creek and approximately a 100 MW rating for emergency conditions. WA.hull -Ln.CP (ih.kesTheodoreCritikos Project Manager TC/MWG/swg Attachments cc:TCS Subcommittee Mr.John Doudna,PTI 001094 .wpt/BL007 rtiy +STONE &WEBSTER --_--om by -\r POWER TECHNOLOGIES,INC.ONE SIERRAGATE PLAZA SUITE 3408 ROSEVILLE.Ca 95678 916 783-3566 TELEFAX 996 783-2086 TELEX 145498 November 4,1992 Mr.Marty GustafsonStone&Webster Engineering Corp. P.O.Box 5406 Denver,CO.80217 Dear Marty: RE:Letter Report On ABB/PTI Study Comparisons We have reviewed the Additional Digital and Analog Simulations performed by ABB and reportedin Revision 0 of their document HAHE 600 035 dated 08/28/92.As was notedin ourSeptember25faxtoyou,we believe that the findings of the ABB report are consistent with the findings derived by PTIin its various studies associated with the Bradley Lake Project. _However,based on comments made at the last TCS meeting,there appears to be some feelingamongtheRailbeltutilitiesthattheABBworkandthePTIworkdonotshowconsistentand comparable results.To address the Railbelt utilities concern,we have performed a detailed qualitative comparison of the ABB work presented in the above noted document to previous work done by PTI.We did not perform any additional simulations to try to specifically duplicate or repeat the simulations presented by ABB.This letter report presents the results of our comparison. The above noted ABB document included five tests.For organizational purposes and to facilitate comparison with PTTs work,we have presented our comparison results relative to each of the specific ABB tests using their test designations.In addition,we have provided a section which provides some general comparison information between the ABB and PTI work. General The tests reported by ABB were conducted on ABB's analog simulator and/or its digital simulation program.These included tests both with and without the Kenai SVCs in service. The ABB digital simulations considered both detailed and reduced Kenai representations for some of the tests.Further,some of the ABB digital simulations considered both detailed and equivalenced Anchorage area representations. In comparing the ABB work to that of PTI,it is only possible to perform the comparisons against PTI digital simulations.PTI did not perform any ofits simulation work on an analog simulator which would allow for direct comparison of two analog simulator results.Further, it should be noted that all PTI digital simulation work was performed using only detailed representations of the Railbelt system.The representations used in the PTI work were changed from time-to-time to take advantage of new or more detailed data.But,the most detailed representation supported by the available data was always used.Thus,the ABB work can only be compared to PTI work based on detailed system representations. CORPORATE OFFICES »1482 ERIE BOULEVARD «PO BOX 1058 ¢SCHENECTADY NY 12201.10SA ©S18 374-1220 --\ r- Page 2 Mr.Marty Gustafson November 4,1992 Test 1.1.1 This ABB test was performed through analog and digital simulations using a reduced system model.This test considered the Kenai system without the SVCs.This test used Kenai loads comparable to a winter condition.It represented a 25 MW Kenai export based on 60.6 MW generation at Bradley Lake using both units,and 33.6 MW generation at Bernice Lake using the two largest units.The system response to a 3-phase fault at Daves Creek on the Lawing 115 kV line with 60-cycle delayed reclosing into the fault was examined. An exact duplicate PTI study case does not exist.However,the ABB case can be compared to PTI's load/generation Scenario C as represented in the Interim Operating Study for the Bradley Lake Project dated March 19,1991.The initial condition power flow diagram forload/generation Scenario C is attached as Figure 1.Load/generation Scenario C represented winter peak Kenai loads with 80 MW of Bradley generation from two units,23 MW of Bernice Lake generation from three units,and 16 MW of Cooper Lake generation from two units.This case had a 38 MW Kenai export,and it represented the use of the Soldotna capacitor bank.The PTI work considered the same 3-phase fault as the ABB work,but with either high-speed or 10-second delayed reclosing into the fault.Stability plots for the high- speed reclosing case are attached as Figures 2 and 3. Thus,the ABB Test 1.1.1 and PTI simulation based on Scenario C differ primarily 1in thefollowingways: Bradley generation level (20 MW more for PTI case) Bernice generation level (10 MW less for PTI case) Number of Bernice units (3 for PTI case vs.2 for ABB case) Cooper generation (16 MW in PTI case vs.none in ABB case)J 4Kenaiexport(38 MW in PTI case vs.25 in ABB case)Ligh SHKenaiload(80 MW in PTI case vs.64 in ABB case)be ©7Soldotnacapacitors(used in PTI case but not used in ABB case)garReclosing(high-speed in PTI case vs.60-cycle delayed in ABB case) The higher load level used in the PTI case is essentially offset by the Cooper Lake generationwhichwasalsousedinthePTIcase,but not used in the ABB case.Thus,80 MW of Kenai load minus the 'extra'16 MW generation contribution from Cooper Lake yields a net Kenai load of 64 MW.This is the same as the net load used in the ABB case.Thus,this in effect implies that the ABB and PTI cases represent the same net load level,but differ in the distribution of the net load on the Kenai system. Allowing for the noted differences,the rotor angle deviations and system voltage responseshowninthePTIsimulationarenotsignificantlydifferentfromthoseshownintheABB analog or digital simulations.Both the ABB and PTI work indicate that the Daves Creek- Lawing disturbance is not extremely severe for the given initial system conditions.The operating limit found in the PTI study for load/generation Scenario C was for 65 MW of generation at Bradley Lake with a 25 MW Kenai export.This limit was based on outagesoftheSoldotna-Quartz Creek 115 kV line which were found to be more severe than the Daves Creek-Lawing outage. ---\r> Page 3 Mr.Marty Gustafson November 4,1992 Test 1.1.2 This ABB test used system conditions similar to Test 1.1.1 above,and utilized both analog and digital simulations.This test is different from Test 1.1.1 in that it represented 90 MW of generation at Bradley Lake using both units,and 18.3 MW generation at Bernice Lake using the two largest units.The system response to the same disturbance was simulated. As for Test 1.1.1,an exact duplicate PTI study case does not exist.However as with ABB Test 1.1.1,this case is also similar to load/generation Scenario C.Recognizing that the effective net system load in the ABB and PTI cases are the same as described above and that the other small differences still exist (i.e.,3 versus 2 Bernice units,usage of Soldotna capacitors,fault reclosing time,etc.),the ABB Test 1.1.2 and PTI Scenario C simulations differ primarily in the following ways: Bradley generation level (10 MW less in the PTI case) Bernice generation level (5 MW more in the PTI case) °Kenai export is now the same in both the ABB and PTI cases The ABB case identified that the Kenai export limit for the Daves Creek-Lawing disturbance was 38 MW based on the results of the analog simulation.This appears to be based on the existence of undamped (but non-growing)voltage oscillations.The export limit based on the results of the digital simulation was found to be 42 MW.However,the limiting stability factor is not apparent from the ABB digital simulation results. The PTI simulation,however,did not specifically identify a Kenai export or Bradley output limit for the Daves Creek-Lawing disturbance.It appears likely,though,from comparing the simulation information that the PTI digital simulation would have shown an export limit for this disturbance to be in the 40-45 MW range.The export limit would most likely have been due to damping considerations since the PTI simulation results at 38 MW export do show the presence of some oscillations.Thus,the ABB and PTI simulation results are not contradictory and agree well with one another. Test 1.2.1 This ABB test is a repeat of the digital simulation portion of Test 1.1.1,but using a detailed representation of the Kenai and Anchorage area systems.This test had the same Kenai load level as Test 1.1.1,and it represented a 25 MW Kenai export.The generation is nearly the same as that in Test 1.1.1 except that the generation level at Bradley Lake is 2.6 MW lower to yield the same 25 MW Kenai export.The factor allowing a lower generation level at Bradley to provide the same Kenai export is the reduction of system losses which occurs in the detailed system representation when loads are distributed in a realistic manner. The results of this test are similar to the results of Test 1.1.1.The main observed differences are in the system voltage characteristics.The detailed system representation has slightlyhigherinitialsystemvoltages.This is more comparable to the voltage levels shown in the PTI simulation.The higher voltages are primarily the result of using a detailed AnchoragearearepresentationwhichallowsthevoltageatUniversityto'float'rather than being rigidlyregulatedasitisfortheequivalentAnchoragerepresentation.Also,this ABB case shows --\- Page 4 Mr.Marty Gustafson November 4,1992 higher post-fault clearing recovery voltages and this is also more comparable to the PTI simulation results. Under ABB's Test 1.2.1 description,variation cases were also described,but power flow and stability results were not provided.These variation cases used the detailed Kenai system representation,but an equivalent Anchorage representation providing either minimum or maximum short conditions.The variation cases had the Bernice Lake generation (33.5 MW worth as used in the initial Test 1.2.1 case)disconnected.This implies that Bradley Lake is the only Kenai generation.Kenai export capabilities of 42 MW and 50 MW were noted depending on the short circuit level of the Anchorage equivalent. An exact duplicate PTI study case does not exist.However,the ABB variation cases established by the removal of 33.5 MW of Bernice Lake generation suggests an initial system condition comparable to PTT's load/generation Scenario D as represented in the Interim Operating Study for the Bradley Lake Project dated March 19,1991.The initial condition power flow diagram for load/generation Scenario D is attached as Figure 4. However,the short circuit level offered by the detailed Anchorage area representation in the PTI Scenario D case does not correspond either to the maximum or minimum short circuit level represented by the ABB equivalents.The 'typical'Anchorage short circuit level available at the University 115 kV bus falls about half-way between the maximum and minimum short circuit levels used in the ABB study. For the ABB variation case described,in order to achieve Kenai export levels of 42 MW and 50 MW,this implies Bradley Lake generation levels of 108 MW and 116 MW,respectively. Generation levels of this magnitude at Bradley Lake were not evaluated in the PTI work for the Scenario D situation.Thus,there is no documentation which shows whether the PTI digital simulation would have identified Kenai export limits for the Daves Creek-Lawing disturbance comparable to those found in this ABB test.This is a mute point since the PTI work identified that Bradley's output was restricted by other,more severe disturbances (e.g., Bradley-Soldotna 115 kV outages)for the Scenario D situation. Test 1.2.2 This ABB test was performed through digital simulations using a reduced system model. Similar test were conducted on the analog simulator during the factory tests in July 1992, but were not documented in this study document.This test considered the Kenai system with the SVCs in service.This test simulated 120 MW of generation at Bradley Lake and 16 MW generation at Cooper Lake.All Bernice Lake generation was off.This test represented Kenai loads for a winter condition,but the load level was adjusted to produce a 75 MW Kenai export.The system response to a 3-phase fault at Daves Creek on the Lawing 115 kV line with 60-cycle delayed reclosing into the fault was examined. The initial system condition used in this test duplicates that used in the initial PTI Kenai SVC Location and Sizing Study and the subsequent refinement studies.This situation was found to present one of the least stable conditions of those considered in the various Bradley Lake studies.However as noted above in the discussion of Test 1.2.1,the short circuit level offered by the Anchorage area representation in the PTT simulation model is --"\r- Page 5 Mr.Marty Gustafson November 4,1992 greater than that presented by the minimum short circuit level represented by the ABB equivalent used in Test 1.2.2. The Daves Creek-Lawing disturbance was not documented in the SVC sizing studies.This disturbance had been shown in previous studies to only cause stability problems when high- speed reclosing into faults occurred.Recommendations against high-speed reclosing on thislinehadbeenmade,and the SVC sizing studies were based on this recommended practice being followed.Other disturbance conditions which did not involve reclosing (e.g.,Soldotna-Bernice Lake 115 kV faults)were found to be more severe than the Daves Creek-Lawing disturbance when high-speed reclosing was not used. Thus,the PTI work focused on the Soldotna-Bernice Lake disturbance.Simulations results for this disturbance using the final SVC sizes and locations is attached as Figure 5.This simulation allows for a reasonable comparison of the ABB and PTI cases even though the disturbance situations are not specifically the same.Both simulations represent the fault and loss of a radial transmission element in the Kenai which results in the loss of Kenai load and creates a higher post-disturbance Kenai export situation. 'Both the ABB and PTI simulation results show that for the initial pre-disturbance condition, the Soldotna SVC is well below its ceiling output level.However,the simulation results indicate a more significant difference for the Daves Creek SVC.In the ABB case,the Daves Creek SVC is initially within a few Mvar of its ceiling output.In the PTI case,it is 10- 12 Mvar from its ceiling output level.This difference is the result of the weaker Anchorage system used in the ABB case which prevents the Anchorage area from providing as much var support as it would typically provide.Further,the simplified ABB representation lumps the loads between University and Daves Creek at Portage,placing the load electrically closer to Daves Creek.Both factors require the Daves Creek SVC in the ABB case to operate at a higher var output under the initial condition than it does in the PTI case. The post-disturbance differences petween the ABB and PTI simulations parallel the above noted pre-disturbance differences.However as noted above the two simulations represent a different disturbance event and different reclosing assumptions,so there are post-disturbance affects which are not comparable.However,the SVC response within the first one second following the initial fault in each case,as well as the dynamic response after the 2.5 second time mark in each case can be compared. The ABB and PTI simulations both show that the Soldotna SVC will reach its ceiling output level for about 0.5 seconds shortly after the initial fault is cleared.However,this SVC stays sufficiently below its ceiling output level for the duration of the simulation in both the ABB and PTI simulations.The dynamic response also compares reasonably well.Both the ABB and PTI cases show that the Soldotna SVC output oscillates about its initial operating point and that it would probably settle out fairly close to its pre-disturbance level.There is a slight difference in the Soldotna SVC output at the end of the simulations.This difference is primarily a result of where Kenai load was tripped.Loss of the Bernice Lake area load in the PTI simulation increase the power transfer from Soldotna to Quartz Creek,and thus impacts the Soldotna SVC more significantly.This specific power transfer increase does not exist in the ABB simulation,thus the Soldotna SVC is not impacted as heavily. "> Page 6 Mr.Marty Gustafson -November 4,1992 The ABB and PTI simulations both show that the Daves Creek SVC will reach its ceiling output level for about 0.75 seconds shortly after the initial fault is cleared.However,theABBcaseshowsthatthisSVCrepeatedlyhitsitsceilingoutputlevelduringsubsequentpowerswingsforthedurationofthesimulation.Further,it appears that the Daves CreekSVCmaysettlenearitsmaximumoutputlevel.The PTI simulation shows that the DavesCreekSVConlyhitsitsceilingononesubsequentpowerswing.Further,the PTI case shows that the Daves Creek SVC output would settle at least 5 Mvar below its ceiling output level. These differences are primarily a result of the same factors which affect the initial operatingpointofthisSVC(i.e.,the short-circuit duty offered by the Anchorage area,and distributionofloadbetweenUniversityandDavesCreek). The ABB test identified a maximum Kenai export level for the Daves Creek-Lawing disturbance of 76 MW based on the digital simulation.A maximum export level was not identified in the PTI study for the Soldotna-Bernice Lake disturbance.However,both simulations show that the system remains stable for the respective disturbances for the same initial Kenai generation and export conditions.This suggests that the two studies are in reasonable agreement and provide consistent results. Test 2 This ABB test was performed only through analog simulations using the reduced system model.This test considered the Kenai system with the SVCs in service.The purpose of this test was to identify the maximum Kenai steady-state export level.This test simulated high generation levels at Bradley Lake (above 120 MW)along with high generation levels at Bernice Lake (above 50 MW).This test represented Kenai loads for a winter condition,but with the load in the Soldotna area switched off to allow the Kenai export to reach a high level.The system steady-state response was tested by bumping'the system due to load switching (off then back on)at Daves Creek. A comparable PTI digital simulation does not exist.The ABB analog simulation identified the maximum steady-state Kenai export limit as being 108 MW.This limit was not specifically identified in any PTI studies using the final SVC sizes and locations.However, the initial Kenai SVC Location and Sizing Study which recommended Daves Creek and Kasilof as the preferred SVC sites,identified the maximum steady-state Kenai export to be 114 MW.However,this limit was based on maintaining acceptable voltage level in power flow analysis cases,rather than by bumping'the system in dynamic simulations. Thus,the Kenai export limits identified in the ABB and PTI work are not directly comparable due to: differences in SVC sizes and locations,and °due to differences in the method by which the limits were determined. However,even given these noted differences,the export limit as determined by the ABB and PTI studies differ by only 7 MW.This small difference suggests that the two studies are in reasonable agreement and that the results complement one another. A PTI study recently completed to examine Kenai spinning reserve utilization capability provides,perhaps,for a better comparison to this ABB test.This case considered summer "> Page 7 Mr.Marty Gustafson November 4,1992 normal load conditions in the Kenai with and initial Kenai export of 75 MW.Initial generation levels were 46 MW at Bernice Lake (maximum summer output capability)and 92 MW at Bradley Lake.Following a resource deficiency in the Anchorage area,the Bradley Lake units were ramped to their maximum physical output limit (125.1 MW). Underfrequency load shedding of 14.1 MW also occurred in the Kenai during this simulation, and the Kenai export went up to and settled at 107 MW.The dynamic response of the system was stable,and some system voltages settled slightly below the 90%level. The results of this digital study compare quite favorably with the ABB analog simulation. It was not determined by the PTI study if the Kenai system could have been stressed any harder and still remained stable.Review of system conditions (i.e.,SVC reactive margins, system voltage levels,etc.)suggest,however,that the post-disturbance system condition represented is very near the maximum limit.Thus,one can conclude that the ABB and PTI simulation work yield comparable results and indicate that the steady-state Kenai export level is near 107-108 MW. Please advise if you have any questions concerning this comparison of the ABB and PTI simulation work. Sincerely, John H.Doudna,P.E. Senior Engineer JHD: Enclosure "> :j BERNICE SERNICE SOLDOTNA Le 6 99868 (rrr 9989 SOLDOTICG woeeaQSLos18"1,5 $__flo.o oa q <0-3 ze 2 oro ade "4 DAVES CR «|r 2 3 9.0 |1.024 9986 ale - 4.3 3.8 SOLD SVS <T x =" a 3.z )fozd-Oh -of.flo.e 3"§ .vie ele °3,390 A -16.8 0.90 Ne 2 rT3>20f ze 2.25 Z ge 950.0S/o-8f >-i é ° -0,9 :10.6 o 7.4 ORTZ CR4Fi.6li7.6°=gos 9967 er ane a4odr*) oo 1.028 29.7 -29.11146.9 3.9 =8.3 6.8h-7.6 ;43.3 9996 . e 11.0 1.025 LAWING sxt urty SO}!1.020 1.022 w1.5 -98 =}3.6 3.7 oatz cr "SY 4.024j2{ 9993 1.8 J qfe ele a '"sotpoTna "¢Y 1.037 i:Tesoro 2M 1.024 9992 2.6 ' 69 tle 3.8 aN7ale :pe oN ' ole704feel BEAVA CR Soo;t*sie 1.927|a 3.3603 o|?028 eet KASILOF SJ ,-1.918 ake -_1 wie{Vv @ ; 70 | BEAVR CR 1 /:fo IGUAEANCHPTale1.017 75 =|6.6 .ba Ca >)boat toad alei7 {4. DIAM RDG cle 1.0189965=)7.5 °--|<f 3 215.4}7 '«zo >2 4.3 a i] i FRITZ CR BRAD LK }9997 §00 4$,0 $40.0 =6.5 <"1.6 2 31.7 4.3 -34,1 34.7 $40.0 6 2.413,7 4.2 <"1.6 L 0.641.020 1.0298.6 12.9 esd CASE C.WINTER PEAK LOAD.38MW EXPORT @ DAVES CREEK.Bf KENAI GEN:80MW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER."ii |THU,FEB 28 1991 11:35 Kv1869 .4138 6290 2 anol CASE C.WINTER PEAK LOAD.36MW EXPORT @ DAVES CREEK. KENAI GEN:BOMW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER.aw4C/3P FAULT @ DAVES CREEK ON LAWING 115KV LINE.TRIP LINE,oo [2]UNSUCCESSFUL HIGH-SPEED RECLOSE FROM DAVES CREEK.SH FILE:38B880C46.CHN Y HEALY J]RELATIVE ROTOR ANGLE ueJi00.00 mT "F=300.0}BG MLSp 7 RELATIVE ROTOR ANGLE "a{100.00 Miers ™"100.01 +O COOPER]RELATIVE ROTOR ANGLE & [100.00 =ae 100.0 ||OoBERNICE2RELATIVEROTORANCLEm 1100.00 easenene e -100.07 oS|BRADLEY 2 RELATIVE ROTOR ANGLE ZO{100-00 _---«=100.0 |fH BRADLEY}RELATIVE ROTOR ANGLE 5|100.00 -_-_---o -100.0 |f)1 |I |iy PRT Y ||3 4 .''2 [oy ':'ae YU . ''3 _' °!'* ; ''4s .i] ',' . °'2 ©'3 ='.é e ..'le i}.U '\'4 .é 44 \t -1 2 .t ¢ ' 1 =''mt .'A !'3f -°'122 e fy we ..a ' A :vi 3 -}+: \' é /:= ;¢ t :8 eo ='-_/? : . " i]BY .'\ ''3toed.A n t Vos oe '{':,!|||J Ly i}yt |3 Ls __ "Th CASE C.WINTER PEAK LOAD.30MW EXPORT @ DAVES CREEK. KENAI GEN:6O0MW @ BRADLEY,23MW @ BERNICE 6 16MW @ COOPER.ao4C/3®FAULT @ DAVES CREEK ON LAWING LISKV LINE.TRIP LINE,«G) UNSUCCESSFUL HIGH-SPEED RECLOSE FROM DAVES CREEK.$s a FILE:28B880C46.CHN =ao"fe ™bey GOLD HILL 138 KV BUS FREQUENCY {hz} [63.000 =====F S000|3AMLP230KVBUSFREQUENCY(HZ)169.0000 0 mmem °$0.000}oF SOLDOTNA _1}$KV BUS FREQUENCY (HZ)Fs J 63.000 ---50.000| BRADLEY 115 KV BUS FREQUENCY (HZ)J 163.000 -----58.000 | ||||I im |||3 9 4 a 8 3=* 3eo =f _j® I !3 $ o -{? a jie t o 3 o =les 3 =+- H3mf 3 ="Te l !!!|!I I 3 i-_Te a -_---as CASE C.WINTER PEAK LOAD.38MW EXPORT @ DAVES CREEK,\)uy%KENAI GEN:80HMW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER.2H4C/3P FAULT @ DAVES CREEK ON LAWING 115KV LINE.TRIP LINE,*fa)UNSUCCESSFUL HIGH-SPEED RECLOSE FROM DAVES CREEK.20 FILE:36880C46.CHN «{SRI_HILL JS RV {Pup «ae [1.3000 wo >0.3000]ArO|RASILOF_J)8 RV {PU}"Ss[1.3000 a |0.3000 |=t ANCHOR POINT 1)$KV_{PU)H {7.3000 aia]0.3000 |re{___DIAMOND RIDGE69 RV (PU)a{1.3000 ore rennn e 0.3000)Oo|FRITZ CREEK 125 KV (PU)in[¥.3000 ---s 0.3000 |Fe{BRADLEY LAKE JES RV (PU)811.3000 --o 0.3000 |ss||i |i |a25agOguna=ee L - 4 a a oe .A Ea-nn b 3 -3oon(0) a 3 on oo 3 oa 4? AR Sid 3 =oo _|]3 o |!!||!|i Dt CASE C.WINTER PEAK LOAD.36MW EXPORT @ DAVES CREEK. KENAI GEN:680MW @ BRADLEY,23MW @ BERNICE &16MW @ COOPER. 4C/3P FAULT @ DAVES CREEK ON LAWING 115KV LINE.TRIP LINE, UNSUCCESSFUL HIGH-SPEED RECLOSE FROM DAVES CREEK. FILE:38B880C46.CHN{DAVES CREER 11S RV (PU) 1.3000 meee ae ">0.3000| {QUARTZ CREER 69 KV {PU}[1.3000 Bereeees ™@.3000| |QUARTE CREER 115 RY (PU) [1.3000 ---Se 0.3000| |BERNICE LARE 69 RV (PU) |1.3000 Con nweeane 0.3000| |SOLDOTNA 69 KV (PU) [1.3000 -----0.3000| |SOLDOTNA JIS KV {PU} 71.3000 -_--_0.3000 | TT rn |TT 3 2 g = "S a i a ji J3 oe =44 g_."Ts 3 _csPo LE i CJ$ =bd Px Se ee = eo _ $ ==-<__._la oy ea | ||.yt !|l !I :30NORTHERNKENAIVOLTAGES09MAR141991THU,TIME SOLOOTNA 9909 ,BERNICE @ERNICE nopec.of >9986 9990 SOLDOTIC a9 i.@ oop >as =9,9 9.9 ¢_flo.o 994 H 3 sea =0.2 Seto _ DAVES CR "le 3.04 :2.off >1.009 9986 si =°.6 coy >3.6 SOLD svs x 1 i i ¢a )Be OH}.- 0$ 12.9 v ze is2.48.4 ts 0.0 fog )ne ' N09 1.4.>isl i er z -3,5 2.6 °e 2.7 Pi.2i4.9%So :lla,9°a1.007 10.6 -10.7/112.9 8.4 "12.4 8.9H-9.2 -33.6 9996 "1.8 1.036 LAWING SKI HILL "IS 1.023 1.013 9.0 8 i!=6.7 6.8 ORTZ CR 1.037 =o 9993 8.8 mle min r ©sotpotna 'XY 1.033 °TESORO AN 1.007 9992 7.9 69 Ihe 6.4 ofn ape TeeyJalanwlan=7aw"1 10 ole peAvR cn goge tk gj 2,027 7.987 2i D we oe -40.6 KASILOF "5 1,014 qnin74mie 6.4 a ate _-DD v ola ajo ojo ole 'ojo o1o70 BEAVR CR wis ANCH PT olw 1.020 7$={1 =4.5 q nwoateale a nig DIAM RDG alu 1.0229965=|-3.8 Tae Le)-mire ae 29.9)7 3s >22.6 a o RITZ CR BRAD LK 9997 500 34,6 '30,03.1 <22482)23.4 3.3 2$.0 25.3 $30.0 qty?4.5 <-1.8 1 0.493.024 1.029 =2.9 0.2 CASE D.WINTER OFF-PEAK LOAD.SMW EXPORT @ DAVES CREEK. KENAI GEN: THU,FEB 28 1991 60MW @ BRADLEY. 11:43 KV:869 .€£138 .€2 30 55%KEN LOAD.75MW EXP @ D.C.120MW @ BRADLEY &16MW @ COOP.10:33Nov301990KENAIVOLTAGESFRI,NO SOLD CAPS.¢25/-10 SVS @ DAVES,#70/-55 SVS @ SOLDOTNA.5C/3P FAULT @ SOLDOTNA @ 0.5.TRIP SOLDOTNA-BERNICE 115KV.TRIP BERNICE &20%OF OTHER KENAI LOADS.NO REMEDIAL ACTION. :FILE:X7SLLLAC.CHN FRITZ CREER JISKY (PO)J J1.1500 oe ee =>@.6500 | ARCHOR POINT JISKV (PO)4.15800 Woe eee eee 6.6500| RASILOF_J)SKV_{pup {1.1300 - ---=me 9.6500| QUARTZ CREEK JISKV (pd) 14.1500 eeseceee °0.6500 | DAVES CAREER )ISKV {PU}[1.1800 ----0.6500| 1 SOLDOTNA_J)SKV_(PD) 11.1500 -o 0.6500 | T Te yet ]l I |T g"tt 8¢a :j 3 a i 43 't ad $i]'[=]x t 3Cysoeif! '8 a ="Ta g =s gnm"Ta i 2 w ' .-J: =3 =3 ° |!|J !i i a n 2/_/ $50 KEN LOAD.7SMW EXP @ D.C.120MW @ BRADLEY &1éHW @ COOP. KO SOLD CAPS.¢25/-10 SVS @ DAVES,#70/-55 SVS @ SOLODOTNA. 5C/3P FAULT @ SOLDOTNA @ 0.5.TRIP SOLDOTNA-BERNICE 115kv. TRIP BERNICE &20%OF OTRER KENAI LOADS.NO REMEDIAL ACTION. FILE:X7SLLL4C.CHN A kK NCE (PO)|lesase ----¢ 0.500 | SOLDOTRA SVS ADMITTANCE{PU}j }0.8000 0.200 | T I Z e Lo +i $|.3 3 ="Ta so3 od 42? gL__boon ed a 3oomPo} a i g -3 3 =2 "Ts ![jt 1 !!g 3:3310NOV301990KENAISVSVALUESFRI,TIME SUMMARY &OVERVIEW OF RAILBELT STUDY REPORTS We have reviewed all of the study reports and documentation produced by Stone & Webster Engineering Corporation (SWEC),SEI,and Power Technologies Incorporated (PTI),concerning the Railbelt.This includes reports and documentation associated directly with the Bradley Lake Project as well as other Railbelt projects (e.g.,Load Shedding Study).This summary only includes references to documentation which addresses or has some direct bearing on the Bradley Lake Project or Kenai export capabilities.Further,this includes work affecting or related to the final design and operation of the Bradiey Lake Project.Thus,this summay does not document work which is related only to the interim operating period of Bradley.The reports and documentation are summarized below in chronological order. Bradley Lake Hydroelectric Project Transmission Line Analysis,September 1983,SWEC e Study based on power flows only. e The Bradley Lake Hydro Plant will consist of two units with a total capacity of 60, 90,or 135 MW,and is scheduled for commercial operation in 1988. e Projected peak load on the Kenai Peninsula is 87 MW in 1988,103 MW in 1995, and 120 MW in the year 2003. _@ The present transmission system on the Kenai Peninsula will be expanded to include a new 115 kV line from Fritz Creek to Soldotna before Bradley Lake is in service. e Existing generating capacity on the Kenai Peninsula is approximately 85 MW,and plants are located at Bernice lake and Cooper Lake. e Two 115 kV lines are required from the Bradley Lake Hydro Station to the Fritz Creek to Soldotna 115 kV transmission line.Each line should be thermally capable of carrying the full output of the plant. e For the 60 or 90 MW Bradley Lake plant size,no additional transmission is required on the Kenai Peninsula or from Kenai Peninsula to Anchorage other than that transmission planned to be added prior to 1988. e For the 135 MW Bradley Lake plant size,a new line from Soldotna to Anchorage is required in 1988,preferably rated 230 kV. e By the year 1995 a new switchyard will be required at Kasilof to interconnect the existing and new 115 kV transmission lines. e-Automatic unit tripping should be installed at Bradley Lake to operate:1)in the event of the loss of an Anchorage tie while it is exporting power,or 2)in the event of the loss of the Bradley Lake to Soldotna line. 001087.wet/BL007 -j1- Transfer Capability of Existing Anchorage-To-Kenai Peninsula 115 kV Transmission Line, February 10,1984,SWEC e Study based on stability analysis by tripping Anchorage unit to determine normal and emergency ratings of Anchorage tie. e Bradley Lake Maximum output 9JOMW. e Spinning reserve from Bradley Lake is 2OMW. e Static Var control was assumed at Portage. e Normal Anchorage tie rating is 77 MW and emergency rating is 90 MW. e SVC at Portage increase tie rating to 110 MW. e Power system stabilizer in Anchorage and in the Kenai improves the transfer capability. e Transfer capability is lower for other faults unless automatic transfer trip of units at Bradley Lake is utilized. e Spinning reserve in the Kenai is reduced considerable because of high line losses during emergency export to Anchorage. e Any hydro unit,including Bradley Lake,will contribute very little,if any,to arresting frequency decline on loss of a generator. Bradley Lake Hydroelectric Project Transient Stability Study,January 1986,SWEC e The Bradley Lake Hydro plant will consist of two units with a total capacity of 90 MW and is scheduled for commercial operation in 1990.An additional 45 MW unit could be added in the future but is not anticipated before the year 2000. e The projected peak load on the Kenai Peninsula is 93 MW in 1990. e It was assumed the spinning reserve should account for the loss of the largest unit on the Kenai Peninsula.Therefore,when Bradley Lake comes on line in 1990,the spinning reserve is 45 MW.This allows enough to cover the loss of one Bradley Lake unit. e A transfer trip scheme is required for the two 115 kV lines from Bradley Lake. e The inertia constant of the turbine/generators at Bradley Lake is not critical. Typical values between 2.0 and 3.0 MW-sec/MVA are adequate. e For a Zone 1 trip on the Bradley Lake to Soldotna fine,high speed deflector operation will minimize rotor angle and frequency deviations.Tripping should be avoided so that system inertia is maximized. D01087.wet/BLOO7 -2- Fritz Creek-Soldotna Line Briefing Document,March 18,1987,SWEC &AEA Emergency rating of Kenai tie to Anchorage is 90 MW. Chugach Electric Association studies indicated its experience was that the tie should be rated at 55 MW. Chugach Electric Association,Inc Stability Study,January 1988,SEI A fault on Bernice 69 kV bus trips all units and results in load shedding in both the Kenai and Anchorage areas. Bradley Lake Hydroelectric Project Stability Study,June 1988,SEI Place into service,as far as feasible,those lines normally operated open.This could greatly increase system reliability,reduce system losses,and help prevent system separation due to the looped lines presently being left open. Even with a high speed transfer-trip relaying scheme on the proposed Bradley Lake transmission lines,the system will swing out-of-step for three phase faults on these lines,whenever Bracley Lake is at full output. At peak load conditions and particularly when the Bradley Lake units are serving Kenai load alone,the method which most often prevents the system from becoming unstable is the tripping of one (1)unit at Bradley Lake.This specifically applies to three phase faults in the Kenai area. For three phase faults between Soldotna-Diamond Ridge and Soldotna-Bradley, reduced generation (only one unit on)would be required to completely circumvent system instability.However,economic gain will greatly outweigh the low probability of a three phase fault occurring on these two lines. At peak load conditions and when Kenai generation is approaching full output,the method which most often prevents the system from becoming unstable is the tripping of one unit at Bradley Lake.This specifically applies to three-phase faults in the Kenai area. During minimum load conditions and particularly when the Bradley Lake units are at full output serving Kenai area loads,the system is very unstable for a three- phase fault anywhere in the system.Dispatch Bradley Lake at minimum load conditions to meet Kenai loads only. Transfer tripping should be installed on the following lines: Bradley-Soldotn 115 kV Line Bradley-Diamond Ridge 115 kV Line Diamond Ridge-Soldotna 115 kV Line 001087.wpt/BLO07 -3- During peak Bradley Lake output,a Critical Clearing Time (CCT)cannot be determined by standard methods.In effect,when a three-phase fault is placed close-in to the Bradley Substation on one of the 115 kV lines,the other Bradley transmission line goes into an "out-of-step”condition. Bradley Lake Stability Study -Phase II,October 1988,SEI With no system changes,the generation at Bradley Lake would have to be reduced substantially to meet the system operating criteria. Transfer-tripping should be installed on the Bernice-Soldotna,Soldotna-Quartz Creek and the Diamond Ridge-Homer 69 kV lines. If the system is not modified from it's present configuration after the Bradley units are added,then serious overvoltages and overferquency conditions may exist in the Kenai area after the system is separated along the University-Daves Creek line. The addition of a 230 kV tie line from University 230 kV bus to Soldotna 115 kV bus nas a tremendous impact on the entire.interconnected Railbelt system.The transient stability limit is greatly improved.Three units at Bradley are possible in the future when this line is added.Only two conditions require special treatment. For faults on either the Bradley-Soldotna 115 kV line or the Soldotna-University 230 kV line,tripping of one Bradley unit is required. The SVS systems did not maintain system stability as studied independently at one bus nor as three SVS's on line simultaneously.Their size would be required to be in the range of 20 MVARS of reactors and 40-50 MVARS of capacitors.Also, tripping of one Bradley unit would be a definite requirement for fauits throughout the Kenai area. A OC line addition on the interconnected Railbelt system does not drastically improve transient stability.In camparison the 230 kV line is much better. The AC-DC converter station at Quartz Creek does its job in damping system power swings.However,the Kenai area is shown to suffer extremely high voltages and frequency for faults in that area.This device leaves the network as "elastic”and unreliable as it is now. Switched series capacitors do not improve stability in the Railbelt system as they might in other networks.Their use is not recommended. Switched shunt devices do not improve stability in the Railbelt system.Their use is not recommended. If the system is to exist as it is now,then a corrective action to minimize the overvoltage and frequency problem is to keep the power transfer along the university-Daves Creek Line to a minimum 5 MW or less. D01087.wpt/BLOO?-4- Railbett Stability Study -Phase!,January 27,1989,PTI a) Cc) The most severe disturbance insofar as Kenai stability is concerned is a three- phase fault near Bradley Lake on the Bradley Lake-Soldotna line. This disturbance gives rise to first-swing,damping and steady-state stabilit problems., Stability solutions included series capacitors,shunt Capacitors,static var compensators,high-ceiling and high initial response excitation systems,power system stabilizers,braking resistors,generator dropping,and deflector run-back. A 230 kV line addition was examined,but did not improve Bradley's stability. Anchor Point and Quartz Creek were considered as SVC locations. Series capacitors were considered for the Bradley Lake-Fritz Creek,Anchor Point- Kasilof,and Soldotna-Quartz Creek lines. Instability occurs between Bradley Lake and Soldotna in most cases. Determining disturbance condition was a 4-cycle,three-phase normally cleared fault. The following base case generation &export conditions were examined.These could all be made stable through use of adequate compensation and controls. Bradley Lake at 120 MW b)Bradley Lake at 120 MW Bernice Lake #3 at 24 MW Bernice Lake #2 at 11 MW Cooper Lake units at 15 MW Cooper Lake units off 68 MW Kenai export 69 MW Kenai export 80 MW Kenai load 50 MW Kenai load Bradley Lake at 120 MW d)Bradley Lake at 90 MW Bernice Lake #2 at 11 MW Bernice Lake #2 at 16 MW Bernice Lake #3 at 20 MW Bernice Lake #3 at 21 MW Cooper Lake units off Bernice Lake #4 at 21 MW 69MW Kenai export Cooper Lake units at 15 MW 70 MW Kenai load 76 MW Kenai export 80 MW Kenai load System is slightly more stable with Bernice Lake generation on. Railbelt Stability Study -Phase Il,March 30,1989 Only one option was tested for a range of operating conditions sufficient to support equipment selection.This included 3-series capacitors,1-SVC,2-braking resistors,deflector run-back,and stabilizers at Bradley. 001087.wpt/BL007 -5 - e Soldotna was considered for the SVC location. e Series capacitors were considered for the Bradley Lake-Fritz Creek,Anchor Point- Kasilof,and Soldotna-Quartz Creek lines. e The following base case generation &export conditions were examined.These could all be made stable through use of adequate compensation and controls."? a)Bradley Lake at 120 MW b)Bradley Lake at 120 MW Bernice Lake #3 at 24 MW Bernice Lake units off Cooper Lake units at 8 MW Cooper Lake units off 76 MW Kenai export 65 MW Kenai export 60 MW Kenai load 40 MW Kenai load c)Bradley Lake at 20 MW Bradley Lake at 120 MW ") Bernice Lake unit off Bernice Lake #3 at 24 MW ° Cooper Lake units off Cooper Lake units at 8 MW 52 MW Kenai import 92 MW Kenai export 70 MW Kenai load 42 MW Kenai load e The equipment options studied supported operation for the four above base case situations.However,operation under base case d,was only marginally stable,and the option was not designed for such operation on a normal basis. e-A 230 kV line addition was examined,but did not reduce the need for compensation or controls. e The 230 kV and 115 kV transmission alternatives require about the same compensation equipment to provide stable operation. e Frequency control and regulation after Kenai islanding was identified as a problem. Kenai-Anchorage Transfer Limits (Correspondence PTI/SWEC/029-L)-November 17, 1989 e Summarized the findings of the Kenai Export Limits Study draft report,the final version of which is listed below. e Discussed combustion turbine rating factors and described a method for utilizing the Railbelt CTs'peak ratings to provide temporary spinning reserve following low frequency conditions. Partial Results from Bradley Surge Tank Study (Fax Correspondence PTI/SWEC/032-F)- November 28,1989) e Included frequency comparison plots for three different hydraulic characteristics at Bradley. 001087.wpt/BL007 -6- e Indicated that a surge tank and 10-second needie stroke time on Bradley provide very little benefit in the first two seconds after loss of generation except where there is very little CT spin available. e Noted that for most cases,load shedding would occur within the first two seconds after loss of generation. Kenai Export Limits With and Without a New Line and Additional Compensation, December 4,1989 e Presents brief analysis of secure and emergency Kenai export limits for a range of compensation alternatives with and without a new 138 kV line. e Analysis considered only steady-state and first-swing stability concerns. e The base case considered in this analysis had three series capacitors and one Static var compensator.Variation cases considered either:a.additional compensation, b.the addition of the line,or c.the addition of the line with additional compensation. e All cases assumed that power system stabilizers,braking resistors and defiector run-back controls were available at Bradley Lake. e-Export limits were defined only for faults on the Soldotna-Bradley Lake,Quartz Creek-Daves Creek,and the new 138 kV line.First-swing stability was tested by normally cleared,6-cycle,three-phase faults on these lines. e For cases without the new line,incremental losses ranged from 25%to 75%for the secure transfer limits which were established by the analysis. e The export limits determined in this analysis are shown in the following table. e The 90 MW transfer capability shown is only marginally stable,and the system was not designed for this level of operation.This transfer limit was only achieved by use of two CTs at Bernice Lake in addition to Cooper Lake and Bradley Lake generation. e With only Bradley Lake generation on-line in the Kenai,the secure export limit was found to be only 65 MW. 001067.wpt/8L007 -7- Condition Compensation Secure Emergency Transfer Losses kee No new line No additional compensation 90 MW 25%90 MW (1 SVS &3 series capacitors) No new line Add compensation #*** Level E -add 1 SC 122 MW 47%122 MW Level A -add 1 SVS ae 105 MW Level B -add 1 SVS &1 SC 140 MW 61%140 MW Level C -add 2 SVS xk 135 MW Level D add 2 SVS &1 SC 155 MW 75%155 MW New 138 kV line No additional compensation 110 MW 12%no limit * (1 SVS &3 series capacitors) New 138 kV line Add compensation ****160 MW 25%no limit * *The emergency export limit ie above the power that ia available for export under any condition (e.g.,all generation at maximum export and load at Summer valley). "a Stability cases were not run for these compensation schemes.Both can be assumed to be stable. aan Incremental losses (i.e., the power flow. SUMMARY -KENAI SECURE AND EMERGENCY EXPORT LIMITS (90/155)?x 75%for the no-new-line cases. the percent of the next 1 MW to be transferred that would be lost to line heating).The losses for the 155 MW no-new-line case and 160 MW new-line case are actual numbers from Others are estimated by multiplying the square of the ratio of lower and higher loadings times the percent loss at the higher loading [i.e.(110/160)?x 25%for the 110 MW new-line case and *#eee Added compensation is that compensation above the 1 SVS and 3 series capacitors presently planned Bradley Governor Third Mode (Fax Correspondence PTI/SWEC/049-F,050-F,March 6,1990 &March 7,1990 Reviewed and commented on Woodward Governor's proposal for implementation of the deflector control mode in the Bradley governor. Recommended 'needle set by power'control over the needles during deflector control mode operation. Recommended use of a droop characteristic based on something other than needle position when in the deflector control mode of operation. Load Acceptance Analysis,April 1990,SWEC An additional governor operating mode providing simultaneous operation of all six needles and allowing for possible deflector run-in will improve unit response and provide added frequency control when Bradiey Lake or the Kenai is operating isolated. This governor modification can be made at little expense. During Kenai import conditions,in order to avoid a collapse of the Kenai system upon the loss of the existing Anchorage-Kenai intertie,combustion turbines must be operated on the Kenai Peninsula regardless of the Bradley Lake needle opening times. Maintain the current load acceptance rate (72 second needle opening time),and current hydraulic and equipment design. Implement an additional needle operating mode utilizing all six needles and allowing for deflecotrs cut into the water stream. Load Acceptance Analysis Report -April 1990 (PTI Portion) identified Bradley's spinning reserve benefit assuming the units could respond at the maximum,physical needle full-stroke rate limits of 72,30 and 10 seconds with all six needles being active. 72 seconds full-stroke needle rate limit is the present design,30 seconds is the fastest needle rate limit allowable on the existing hydraulic system,and the 10 second full- stroke rate limit assumed the use of a surge tank. For interconnected system operation,operation of Bradley at the above needle rate limits allowed it to replace 27 MW,27 MW and 45 MW,respectively,of combustion turbine spinning reserve. 001087.wpt/BLOO7 -9- The primary contribution of this Bradley Lake spinning reserve is to allow combustion turbines to be operated at their peak ratings for short periods to avoid underfrequency load shedding.Even the 72 second needle stroke-rate limit will allow Bradley to accept load to back the combustion turbines down within their base rating. The spinning reserve contribution from Bradley may be limited by Kenai export limit constraints rather than the available generation at Bradley. The use of needie opening times less than 72 seconds does little to avoid load shedding.. Under Kenai isolated conditions,the 72,30 and 10 second needle-stroke rates will provide for 3 MW,0 MW,and 10 MW of load pick-up,respectively.The 30 second needle-stroke rate which does not have a surge tank actually degrades Bradley's load pick-up capability in the first few seconds. During Kenai import conditions,combustion turbines must be operated to avoid severe load shedding in the Kenai regardless of the needle-stroke rate utilized on the Bradley units. An additional governor mode providing simultaneous operation of all six needles and allowing for deflector run-in will improve unit response. For rapid needle load acceptance at Bradley,growing power and voltage oscillations were noted in the simulations.These oscillations were most pronounced when the 10 second needie-stroke rate was used. Utilization of Bradley's spinning reserve is dependent on all automatic schemes functioning properly. Short Circuit and Voltage Profile Study (Draft)-May 15,1990 identified series capacitor locations,fault levels for specification of series capacitors and SVCs,and defined fault duty on existing and new circuit breakers and other equipment. Identified fault levels both with and without the use of series capacitors. Identified the effect on fault levels of a third Bradley unit and additional transmission lines. 001087.wpt/BL007 -10- Fax Correspondence PTI/SWEC/064-F -May 23,1990 Noted the presence of control instabilities associated with the Woodward Governor design proposed for Bradley. identified this control instability as a result of the power feed-forward control used on the needles to speed up Bradley's response. Control instability exists for both needle control and defiector control,but is worse when the unit is in the deflector control mode. Recommended the elimination of the power feed-forward control on the needles. Braking Resistor and Deflector Runback Triggering (Draft)-May 29,1990 Performed to select a method for applying the braking resistors and initiating deflector run-back at Bradley in response to system disturbances. Goal was to select initiating methods which wiil reliably apply the proper remedial action and which will minimize remedial action response to non-critical system disturbances. Study focused most heavily on the transient stability of the Kenai system. Transient stability was only found to be a problem during heavy Kenai export conditions and when generation at Bradley exceeded 90 MW. The results were for the system configuration utilizing three series capacitors and a single SVC at Soldotna. Three-phase faults were found to be the only faults which cause transient instability when applied to elements not a part of the primary 115 kV transmission path between Bradley and University. For some fault locations,slow clearing or reclosing associated with a three-phase fault must occur in order to result in transient instability. However,all Kenai three-phase faults during heavy export conditions severely disturb the system and require insertion of one 25 MW braking resistor. One braking resistor should be triggered by low phase voltages at Bradley after a 2- cycle time delay when exports at Daves Creek exceed 50 MW. D01087.wpt/BLO07 -11- e All faults near Soldotna on the Soldotna-Diamond Ridge line,three-phase faults near Bradley on the Bradiey-Diamond Ridge line,and any event which opens the Bradley- Soldotna line will cause Bradley to be transiently unstable when Bradley's output is above 90 MW. e These disturbance require application of one 25 MW braking resistor and deflector run- back on Bradley to the 90 MW level. e Any disturbance which islands the Kenai will require deflector run-back at Bradley Lake to meet the overspeed criteria. e Deflector run-back alone is adequate to meet the islanding overspeed criteria when the Kenai export is 20 MW or less. e Deflector run-back plus the application of one braking resistor is adequate to meet the islanding overspeed criteria when the Kenai export is above 20 MW but is 50 MW or less. e Deflector run-back plus the application of both braking resistor is required to meet the islanding overspeed criteria when the Kenai export is above 50 MW. e-Braking resistors need to be removed in sequential steps when both are used. e The Kenai is more stable when Kenai combustion turbine generation is on-line. e The Kenai is transiently stable following three-phase faults without the use of braking resistors or deflector run-back for Kenai exports up to 75 MW when Kenai CT generation is on-line and the output at Bradley is 90 MW or less. e Normal governor action on Bradley Lake alone can limit Kenai overspeeds to about 63 Hz following a 75 MW load rejection. e The Bradley governors as presently designed do not respond properly when braking resistors are used to control overspeed following load rejections. e.Governor modifications are required to provide forced deflector run-back which is independent of the governor PID controls. D01087.wpt/BL007 -12- Thoughts on Alternatives for Bradley Project (Fax Correspondence PTI/SWEC/068-F)-June 7,1990 Response to SWEC request to identify other option available for Bradley Project which would eliminate the need for braking resistors,deflector run-back,and complicated initiating logic proposed in the May 29 report. Indicated the need to eliminate high-speed reclosing in lines in the Kenai.Indicated that high-speed reclosing would result in instability without the use of braking resistors and deflector run-back. Indicated the need to raise the Kenai overfrequency limit to 63 Hz.This would only affect the setting of the Tesoro overfrequency relay. Stated the following operating levels which were envisioned to be possible if braking resistors and deflector run-back were eliminated: a)90 MW (approximate)generation capability at Bradley with full reliability (i-e., stable following faults which do not island the Kenai). b)120 MW emergency generation capability at Bradley (i.e.,steady-state stable and within voltage limits,but not able to tolerate faults). c)75 MW Kenai export capability at Daves Creek (i.e.,the stability limit for conditions where Sradley output does not exceed 90 MW). Above operating levels were based on the use of three series capacitors and one static var compensator. Istanded Operation Study (Draft)-June 18,1990 The first portion of this study was a complement to the Braking Resistor and Deflector Runback Triggering Study,and examined voitage performance in the Kenai following separation from the remainder of the Railbelt system. The second portion examined the performance of the Kenai when operating as a totally separate system. This study represented the use of the three series capacitor and one SVC system configuration. Voltage performance of the Kenai following separation under heavy export conditions exceeds the voitage criteria. Peak voltages following separation are about the same whether or not braking resistors and deflector run-back are used. 001087.wpt/BLOO7 -13- e Voltage performance was examined mainly for Bradley and Cooper being the only Kenai generation. e The presence of other Kenai generation improves voltage performance. e Kenai separation due to a fault results in higher overvoltages immediately after fault clearing due to the SVC and Bradley exciters being driven to ceiling output by the fault. The power system stabilizer also aggravates the overvoltage condition immediately after separation. e _Rapidly tripping a Soldotna capacitor assists in overvoltage control. e For the Kenai operating as a totally separate system,voltage performance is within criteria following faults and loss of a large portion of Kenai load. e Frequency deviation is the most significant concern when the Kenai operates as a totally separate system with only the Bradley and Cooper units on-line. e Pick-up of 3 MW and 5 MW of load will cause the Kenai frequency to drop to 59.5 Hz and 59.3 Hz,respectively. e Loss of 10 MW of load will cause the Kenai frequency to rise to 61.2 Hz. ®With both Bradley units on-line,but only one operated in the deflector control mode, pick-up or loss of 10 MW of load will result in a Kenai frequency excursion to 59.6 Hz and 60.4 Hz,respectively. e Frequency performance for pick-up and loss :*10 MW of load is only marginally improved if both Bradley units are operated in the deflector control mode. ®With the Kenai operated as a totally separate system and the Bradley output in the 60-70 MW range,loss of the Bradiey-Soldotna line increases Kenai losses by 16 MW. This appears as a load pick-up which is larger than any normally expected feeder load pick-up situation. e With Bradley output of 30 MW or less,the Bradley-Soldotna line outage does not pose any significant problem. 001087.wpt/8L007 -14- Fax Correspondence PTI/SWEC/073-F -July 2,1990 Presented results of simulations done to investigate Bradley's load pick-up capabilities when operating on an islanded Kenai system in the needle contro!mode,but without power feed-forward controi on the needles. Noted only a slight decrease in frequency (0.02 Hz)for a 3 MW load pick-up due to elimination of the power feed-forward control on the needles. Presented results showing a 1 Hz improvement in Bradley's overspeed control capabilities when the deflectors are positioned closer to the edge of the needie stream than proposed by Fuji. Fax Correspondence PTI/SWEC/074-F -July 3,1990 Presented resuits of simulations done to investigate a suggestion made by Woodward of a method of forcing deflector run-back in response to large Kenai load rejections. The results of this analysis indicated that the method proposed by Woodward had significant drawbacks.Large frequency under-shoot could result from this method. Noted that use of this control method following load rejections could be risky,and that it was difficult to predict the result from this method. Fax Correspondence PTI/SWEC/076-F -July 6,1990 Presented more results of simulations done to investigate Bradiey's load pick-up capabilities when operating on an islanded Kenai system in the needle control mode, but without power feed-forward control on the needles. Noted that for islanded operation with only a single Bradley unit there was a significant decrease in frequency (0.15 Hz)for a 3 MW load pick-up due to elimination of the power feed-forward control on the needles. Presented results without power feed-forward contro!on the needles,but with increased needle PID gains. identified that only a slight increase in needle PIO gains over those suggested by Woodward would be possible before control instability became a problem. D01087.wpt/BL007 -15- Fax Correspondence PTI/SWEC/078-F,July 10,1990 &079-F,July 11,1990 Presented more results of simulations done to investigate Bradley's load pick-up capabilities when operating on an islanded Kenai system in the needle control mode, but without power feed-forward control on the needles. Noted that increases in only the integral portion of the needie PID gains would restore some of the load pick-up response lost by elimination of the power feed-forward control without experiencing control instability. Braking Resistor Requirements Study (Letter Report)-August 23,1990 This report examined braking resistor requirements given recent changes associated with the Bradley Lake Project. These recent changes were noted as: a)elimination of series capacitors as a possible option b)relaxation of the overfrequency criteria c)moderation of Bradley output expectations d)adoption of generator tripping as an acceptable option Kenai performance following islanding under export conditions was re-examined. improved deflector response,compared to that used in previous studies,was modeled on Bradley. With only Bradley and Cooper generation in the Kenai and Bradley at 120 MW output, overfrequency following a 75 MW Kenai load rejection was limited to 62.8 Hz. With Bradley,Cooper and Bernice Lake generation and Bradley at 90 MW output, overfrequency following a 75 MW Kenai ioad rejection was limited to 62.0 Hz. Bradley stability following disturbances which do not island the Kenai was also re- examined. if Bradley output expectations are reduced to 90 MW,braking resistors are not required following major disturbances which do not island the Kenai. Tripping one unit at Bradley in response to major disturbances will provide the transient and steady-state stability margins necessary for operation of Bradley up to 120 MW. Unit tripping is simpler and less costly to implement and provide benefits a braking resistor Cannot provide. 001087.wpt/BL007 -16- Generator tripping may provide more corrective action than is required under certain circurnstances. Proper scheduling of the Bradley units can minimize the over correction provided by generator tripping. Kenai SVS Location and Sizing Study (Draft)-September 24,1990 This study was done to identify the requirements for static var compensators to support the Bradiey addition and the location for the SVCs. Noted recent decision to exclude series capacitors as a transmission alternative.Also noted moderated Kenai system expectations,relaxed frequency criteria,and the acceptance of generator tripping at Bradley as a feasible method of stability enhancement. The design criteria used in the study required the Kenai and Bradley to remain stable following disturbances for Kenai export levels up to 75 MW and Bradley Lake generation levels up to 90 MW. Bradley generation levels of 120 MW must be achievable,but unit tripping for stability enhancement may be used at such generation levels. Daves Creek and Quartz Creek were considered as possible sites for the northern Kenai SVC.Soldotna,Kasilof and Anchor Point were considered as possible sites for the southern Kenai SVC. The size of the northern SVC is primarily a function of the Kenai export level to be supported.The size of the southern SVC is primarily a function of the Bradley to Soldotna power transfer level to be supported. Two SVCs were identified,one at Daves Creek and one at Kasilof,which met the above criteria.These SVCs also supported steady-state emergency Kenai exports of approximately 120 MW. An SVC with a rating of 20 Mvar inductive to 35 Mvar capacitive was recommended for Daves Creek. An SVC with a rating of 60 Mvar inductive to 35 Mvar capacitive was recommended for Kasilof if tripping of the Soldotna capacitors was not used as part of the overvoltage control strategy.Otherwise,an SVC with a 45 Mvar inductive to 35 Mvar capacitive rating was recommended. DO1087.wpt/BLOO7 -17- These SVCs were sized based on the continued use of the Soldotna capacitors. Kenai export and Bradley generation levels had to be restricted if either of the SVCs was out of service.Outage of the Kasilof SVC was the most restrictive. Circuit breaker additions were recommended for Kasilof. Overvoitage tripping of the Soldotna capacitors was recommended as part of the SVC compensation plan. Supplement to the Kenai SVS Location and Sizing Study for Evaluation of the Single SVS Alternative (Letter Report PTI/SWEC/089-L)-October 5,1990 This study noted that the size specified for the Daves Creek SVC in the initial study was in excess of what was actually needed to meet the design criteria. This study identified that the Daves Creek SVC capacitive capability could be reduced to 25 Mvar from the 35 Mvar originally indicated. This reduces size of the Daves Creek SVC would satisfy criteria,but would reduce the Kenai emergency steady-state export limit to about 114 MW. This study focused on the performance of the Kenai with a single +60 Mvar SVC located at Soldotna. This study also assumed the Soldotna-Quartz Creek 69 kV line would be upgraded to 115 kV operation. The single SVC and line upgrade option would only provide for about 107 MW of Kenai emergency steady-state export capability. Loss of a single SVC would impose a 5 MW larger restriction on Bradley's output and a 13 MW larger restriction on Kenai export compared to the two-SVC scheme with the Kasilof SVC out of service. The single SVC provides overall better voltage performance following isolation of the Kenai under heavy export conditions. Post-isolation overvoltage performance is nearly independent of the line loss which causes the Kenai system to become isolated. 001087.wet/8L007 -18- e The Kenai system is stable following the loss of the existing Soldotna-Quartz Creek 115 kV line. e Replacement of the Quartz Creek transformer is not necessary. e Kenai export and Bradley output limits are the same as the two-SVC scheme. Supplemental Braking Resistor Study (Letter Report PTI/SWEC/091-L)-October 15,1990 e Further examined Kenai export and Bradley generation leveis which could be tolerated without exceeding 61.5 Hz following isolation of the Kenai. e information was developed for scenarios with and without braking resistors. e Only hydro generation was modeled as being on-line in the Kenai. e Two 25 MW braking resistors rated for six-second operation can keep frequency under 61.5 Hz following interruption of a 75 MW export. e The use of braking resistors results in multiple overfrequency peaks due to upward frequency excursions each time a brake is switched off. e Without braking resistors,Kenai export will have to be limited to 25 MW to keep the frequency under 61.5 Hz following interruption of the export. e Without braking resistors,the Bradley governors return the Kenai frequency to the final steady-state level more quickly. Bradley Lake Stabilizer Options (Letter Report PTI/SWEC/092-L)-October 15,1990 ®This study compared the oscillation damping provided by an electrical power input stabilizer at Bradley versus an accelerating power input stabilizer. ®It was demonstrated that there is a definite need for stabilizers of some type at Bradley Lake. e It noted that stabilizers on the SVC will also be beneficial to system performance,but may not be sufficient to provide stability at Bradley following outages of the Bradley- Soldotna line. D01087.wpt/BL0O7 -19- It was demonstrated that both types of stabilizers on Bradley will produce undesirable effects on system voltage for isolation of the Kenai under export conditions,but that the effects are worse with the electrical power input stabilizer. It was demonstrated that the electrical power input stabilizer will cause +10%voltage deviations at Bradley during fast unit loading changes such as can occur during deflector control.Voltage changes of only +1%occurred when an accelerating power input stabilizer was used. It was shown that the southern Kenai SVC would need to have 15 Mvar more inductive capability if an electrical power input stabilizer was used to provide the same load rejection overvoltage control which is achieved when an accelerating power input stabilizer is used. Kenai Overfrequency Control by Tripping Cooper Lake (Letter Report PT!I/SWEC/094-L)- October 29,1990 This study examined the affect of tripping the Cooper Lake hydro units to assist Bradley Lake in overfrequency control following isolation of the Kenai under heavy export conditions. This tripping action was demonstrated for a 75 MW Kenai load rejection. Two methods were examined for tripping the Cooper units.One assumed tripping based on frequency at Cooper Lake,and the other assumed tripping based on trip transfer logic. The two methods provided essentially the same results.- Tripping the Cooper Lake units only reduced the Kenai load rejection peak overfrequency by 0.3 Hz compared to overfrequency control solely by governor action at Bradley Lake. The benefits of tripping Cooper Lake for overfrequency control were not significant, and it was recommended that overfrequency tripping not be installed on the Cooper Lake units. SVS Refinement Study (Letter Report PTI/SWEC/096-L)-November 7,1990 This study was requested by the TCS to further refine the size and location for the SVCs.The TCS concluded that the two-SVC alternative was preferred. 001087.wpt/BLOO7 -20- This study considered possible reductions in SVC inductive capability due to the decision to use accelerating power stabilizers at Bradley. This study considered the affect of Cooper generation on SVC inductive size. The needed capacitive size for the Daves Creek SVC was evaluated for the second Anchorage-Kenai intertie with a 100 MW Kenai export requirement. The capacitive size for the southern SVC was evaluated for location at Soldotna versus Kasilof location recommended in the original study. The needed extra SVC capacity was determined which would allow for non-optimum operation of the Soldotna capacitors. Overvoitages following isolation of the Kenai under export conditions were worse when Cooper Lake generation is on-line compared to when an equivalent amount of generation is supplied from Bernice Lake. To keep all swing voltages to 115%or less for loss of the Quartz Creek-Daves Creek line,an SVC at Soldotna needs an 80 Mvar inductive capability and an SVC at Kasilof needs a 70 Mvar inductive capability. Overvoltage performance is improved for the Soldotna-Quartz Creek and Quartz Creek- Daves Creek outages if 10 Mvar of inductive SVC capability is shifted from the Daves Creek SVC to the Kasilof or Soldotna SVC.The Daves Creek SVC should be rated for 25 Mvar capacitive to 10 Mvar inductive. If less than optimum use is made of the Soldotna capacitors,an SVC at Soldotna needs a 60 Mvar capacitive capability and an SVC at Kasilof needs a 45 Mvar capacitive capability. Kasilof is the electrically preferred SVC location,but it is not vastly superior to the Soldotna location. The Daves Creek SVC needs a 60 Mvar capacitive capability to support a 100 MW Kenai export with the second Anchorage-Kenai intertie. Additional SVS Refinement Case (Letter Report PT!/SWEC/099-L)-November 28,1990 This study investigated improvements in overvoltage control which would be obtained by faster tripping of the Soldotna capacitors following isolation of the Kenai under heavy export conditions. 001087.wet/BL007 -21- Noted the TCS recommendation to use Soldotna as the southern Kenai SVC location versus Kasilof. Demonstrated overvoitage performance for loss of the Daves Creek-Quartz Creek line when the Soldotna capacitors are tripped after the Soldotna SVC reached its inductive limit and the voitage at Soldotna reached 110%. It showed that only the voitage at Fritz Creek exceeded the 115%overvoitage limit under this control strategy. Soldotna SVS Size W/O 115 kV Capacitors (Letter Report PTI/SWEC/100-L)-November 30, 1990 e This study evaluated the required size for the Soldotna SVC if the existing capacitors were removed. lt assumed a 25 Mvar capacitive to 10 Mvar inductive SVC at Daves Creek as determined in a previous study. It determined SVC requirements with Bradley Lake and Cooper Lake being the only Kenai generation on-line. It determined the SVC size needed for stable operation and satisfaction of voltage criteria for the following conditions: a)three-phase fault on the Bradley-Soldotna line with 90 MW of generation at Bradley and a 53 MW Kenai export. b)three-phase fault on the Soidotna-Bernice Lake line with 120 MW of generation at Bradley and a 75 MW Kenai export. c)Isolation of the Kenai due to a three-phase fault on the Daves Creek-Quartz Creek line with 120 MW of generation at Bradley and a 75 MW Kenai export. Recommended the size of the Soldotna SVC as being 70 Mvar capacitive to 40 Mvar inductive. Kenai Import Study (Letter Report to Afzal Khan)-June 13,1991 This study identifies the maximum Kenai imports which can be accommodated in the future with only Bradley Lake on-line. The maximum imports with Bradley were established such that they yield the same level of load shedding in the Kenai as would be expected for the same system situation when CT generation is on-line in the Kenai. 001087.wet/BL0O7 -22- e This study analyzed system response for historical Kenai operating conditions.Nine historical load/generation scenarios were identified by the TCS. e Load shedding is necessary for survival of the Kenai following significant resource deficiencies.It is always needed for a hydro-only generation condition,and is needed for most CT generation conditions. e Existing Kenai load shedding relays provide for 10 discrete load shedding events. e For the historical load and import conditions,the number of load shedding events with CT generation versus the number which would occur if Bradley replaced all the CT generation are summarized in the following table: Summary of Cases With Kenai Load Shedding Relays In Service With CT Gen __With Bradiey _ #Load Final #Load Final Shed Freq Shed Freq Case Events (Hz)Events (Hz) Summer 1 5 59.3 10 60.1 Summer 2 2 59.3 5 60.4 Summer 3 5 59.7 10 60.2 Winter 1 5 59.6 10 60.2 Winter 2 10 60.7 10 60.3 Winter 3 2 59.3 10 60.3 Spring 1 10 59.8 10 60.3 Spring 2 10 60.6 10 60.2 Spring 3 10 59.7 10 <56.0 e Kenai load shedding occurs even when CT generation is on-line,but the presence of CT generation limits the number of load shedding events. e The present Kenai load shedding is sufficient to arrest frequency decay following significant resource deficiencies under most conditions. e Modest overshedding can occur for certain situations and is particularly noticeable when only Bradley is on-line. 001087.wpt/BL007 -23- The Soldotna load shedding relay has a long delay time.This did not create probiems in this particular study,but the possibility exist that there could be situations where a faster relay at Soldotna could prevent further load shedding. The following guidelines were developed based on the objective of limiting the amount of load shedding when Bradley generation is on-line to that which would have been expected under historical system conditions using CT generation: 2 a)With only two Bradley Lake units on-line,Kenai imports should be limited to no more than 22 MW. b)With both Cooper Lake and both Bradley Lake units on-line,Kenai imports should be limited to no more than 25 MW. c)When the Kenai must operated isolated,one of the large CTs should be operated along with the Bradley units. Using Bradley generation exclusively in place of CTs can,but does not always,restrict Kenai imports below past historical levels in order to limit load shedding to levels expected for these historical situations. For a hydro-only generation situation in the Kenai,the total hydro generation must exceed the non-shedable Kenai load.A level of two times the non-shedable load was shown to be adequate. The present Kenai load shedding scheme provides favorable action when the Kenai is dominated by CT generation. When the Kenai is predominately a hydro-based system,the present load shedding scheme appears to provide less than optimum performance. Additional Kenai Import Study (Letter Report to Afzal Khan)-June 21,1991 This study identified those Kenai import levels at which load shedding transitions (i.e., no load shed to stage-1,stage-1 to stage-2,and stage-2 to stage-3)would occur following isolation of the Kenai. Such import levels were determined for: a)a CT-based system with only Bernice Lake 3 &4 on-line b)a hydro-based system with only Bradley Lake and Cooper Lake on-line Cc)a composite system with Bradley,Cooper and Bernice Lake 3 on-line. 001087.wet/BLOO7 -24- e Two methods were used to establish the Kenai import levels at which load shedding transitions would occur.One method maintained a constant generation schedule and changed Kenai import by scaling Kenai load.The second method maintained a constant Kenai load level and changed Kenai imports by scaling Kenai generation. e The results from the two methods are shown in the following tables: Table 1 KENAI IMPORT LEVELS AT LOAD SHEDDING TRANSITION POINTS (CONSTANT KENAI GENERATION SCHEDULE) Load Shedding CT-Only Hydro Hydro-CT Transition Based Based Based Point System System System Oto 1 14 MW 7 MW 14 MW ito 2 24 MW 14 MW 28 MW 2to3 35 MW 29 MW 49 MW Table 2 KENAI IMPORT LEVELS AT LOAD SHEDDING TRANSITION POINTS (CONSTANT KENAI LOAD LEVEL) Load Shedding CT-Only Hydro Hydro-CT Transition Based Based Based Point System System System Oto 1 14 MW 7 MW 14 MW 1to2 24 MW 12 MW 23 MW 2to3 31 MW 19 MW 32 MW D01087.wpt/BLOO7 -25- e The method used to identify Kenai import levels at which load shedding transition occurs does have some effect on the results,particularly for the stage-2 to stage-3 toad shedding transition point. e The method used oniy has a smail effect on the results up to the stage-1 to stage-2 load shedding transition point. e The Kenai system relying on two combustion turbines can import about twice as much power as a totally hydro-based system and achieve the same level of load shedding following isolation. e With Bradiey Lake generation on-line,comparable import levels can be achieved by operating one CT unit in the Kenai. Revisions to June 13,1991 Kenai Import Study (Letter Report to Afzal Khan)-June 25,1991 e This study was run to correct the representation of load levels on the system between University and Daves Creek to better match the historical situation. e This only affected the winter and spring load condition cases. ©The results are shown in the following table.The results which are different from the original study are denoted by an asterisk. Summary of Cases With Kenai Load Shedding Relays In Service With CT Gen With Bradley #Load Final #Load Final Shed Freq Shed Freq Case Events (Hz)Events Hz) Winter 1 5 59.6 10 60.2 Winter 2 10 60.6°10 60.2° Winter 3 O°59.3 5°60.2° Spring 1 10 60.8°10 60.3 Spring 2 10 60.3°10 60.1° Spring 3 5°58.8°10 52.8° e The change in Kenai imports resulting from the representation of larger load amounts between University and Daves Creek did not have a significant effect on the results. D01087.wpt/BL007 -26- e The observations drawn in the original study are still valid. Fax Correspondence to John Yale -June 30 &July 1,1992 e A brief study was done to investigate the cause of frequency oscillations which occurred on June 3 following the isolation of the Kenai with only Bradley generation on-line. e It was concluded that the on-line needle PID gain settings used in the Bradley Lake governors provide unstable control on an isolated Kenai system with no other fast- responding generation on-line. e The control instability is worse when both Bradley units are on-line. ©AGC control may also contribute to the frequency oscillation problem observed during the June 3 event. e Use of the off-line needle PID gains substantially improves frequency performance when Bradley is the only generation on an isolated Kenai system. _@ Putting one Bradley unit in deflector control mode provides stable control. e-Automatic control actions to place one Bradley unit into deflector control mode when the Kenai becomes isolated was suggested. Kenai UF Load Shedding (Fax to Burlingame,Haagenson &Hembree)-July 9,1992 ®This work is part of the Railbelt Underfrequency Load Shedding Study. e Examined Kenai load shedding requirements for winter peak load conditions with only 16 MW of hydro generation on-line (equivalent to Cooper output). e All cases used a Bradiey unit instead of Cooper.Transfer to deflector control mode was simulated after islanding,and AGC control over Bradley was suspended upon islanding of the Kenai. e Shedding 75%of the total Kenai load provided the best frequency performance for a hydro-only generation situation.This level of shedding remains viable under high Kenai import conditions with some CT generation on-line. e Two possible UF load shedding schedules were suggested as shown in the following table: 001087.wet/BLO07 -27- --e | Pick-Up Kenai UF Load Shedding Schedule Option #1 Option #2 59.0 Hz 10%10% 58.7 Hz 25%40% §8.2 Hz 40%25% | Both schedules can result in overshedding given specific Kenai generation schedules. Allocation of load shedding among three !oad shedding stages is not highly critical to frequency response on the islanded Kenai system. However,Kenai load shedding response under interconnected,high Kenai export conditions needs to be considered in selecting load shedding for the Kenai.Shedding large amounts of Kenai load under such conditions could cause the Kenai system to go out-of-step. The majority of Kenai load shedding may have to be lumped in the third stage. Kenai islanded frequency response following islanding under high import conditions results in frequencies both lower than Bradley's underfrequency trip point and higher than Cooper's overfrequency trip point. The underfrequency tripping on Bradley needs to be lowered or eliminated. The overfrequency tripping on Cooper needs to be modified or eliminated. The underfrequency trip point on Bernice Lake 3 &4 should be lowered to 57 Hz. Bradley Load Pick-up Capability in Deflector Control Mode (Letter Report PTI/SWEC/108-L)- July 10,1991 This study identified the maximum load pick-up capability provided by the Bradley Lake units when operating in the deflector control mode. A 15 MW load pick-up capability had been established in the surge tank analysis,but a maximum was never determined. 001087.wpf/BLOO7 -28- This study represented an isolated Kenai system with both Bradley Lake units serving the entire Kenai load.The units were equally loaded and operating in the deflector control mode with all six needles fully open. Load pick-up was simulated to identify the maximum which could be abruptly added to the system before reaching first underfrequency load shed point. Droop settings of 1%and 5%were tested. The results are shown in the following table: Maximum Load Pick-up Deflector ili Droop 46 MW 5% 49 MW 1% The load pick-up of the Bradley units when in deflector control mode is substantial,but is less than the units'available spinning reserve when conditioned by having to meet minimum frequency objectives. The droop setting does not significantly change the load pick-up capability. The droop setting does significantly effect the system frequency error within a short period (10 seconds)following the load pick-up event. Simulation of June 3 Event (Fax to John Yale)-July 13,1992 The June 3 event was simulated using the PSS/E Bradley model with the on-line needle PID gains. There were a few differences between the simulation and actual event as recorded on the DSM. The simulation confirmed that the large frequency oscillations occurred as soon as the deflector came out of the needle stream. Bradley Islanded System Response (Fax to John Yale)-September 8,1992 This further investigated control instability of the Bradley units when operating on an islanded Kenai system. 001087.wpt/BLOO7 -29- Two causes which contribute to control instability of the Bradley governors when operating on an islanded Kenai system were documented. These causes are the on-line needle PID gains and the needle PID integral gain addition function. The integral gain addition function is the most de-stabilizing factor. The integral gain addition function when remaining in service on one Bradley unit was found to counteract the stabilizing effects of the deflector control mode on the other Bradley unit. It was recommended that the gain addition functions on the Bradley governors be disabled.This can be implemented by changing governor 'tuneables'. Elimination of the gain addition function will not totally solve the control instability problem,but will significantly minimize the problem. Bradley Modeling Results (Fax to John Yale)-September 24,1992 It was noted that the Bradley model developed for PSS/E did not yield the same overfrequency response as measured by the DSM when simulating the July 8 disturbance event. Verification cases were run against the August 1991 load rejection tests performed on the Bradley units during the commissioning tests. The-model did not match the measured data either in overfrequency performance or in deflector movement. The deflection characteristics used in the model and derived from the Fuji data were found to be suspect. The deflection position indication used by the governors at Bradley were found to be suspect and may have a significant time delay associated with it which interferes with the action of the governor. New field tests on Bradley were recommended to develop actual power versus deflector position characteristic for use in the model. It was recommended that the response of the deflector position indicators used on the Bradley units be evaluated through field tests. 001087.wpt/BL007 -30- Gi:Lhe>pe Eeae, y2R 200d .WVZ2:60ring VeTMsueI,worgy Gorzyosaauverst -32310 aarqy asuoqadaiaSEeeEeeeoeeeoeeeMr.Mike Kelly General ManagerGoldenValleyElectric Association,Inc.Bo \b Fairbanka,AK 99707 : |Fle 6?aPAITTIIIWNX|:ay SUBJECT:INTERIM BRADLEY OPERATIONS be Dear Mike:i csmrmirs oo, ;BB a.2D uggs Re 'During the January 13,1992,Railbelt Manager's meeting,HEA wasaskedtosupportarelaxationofexistingvoltage:swing criteria.This would allow Bradley Lake to be scheduled up to 90 MW on a regular basis pending installation of the Kenai SVS units.ThisproposalwasprimarilytheresultofarecentanalysisbyPTIwhichconsideredKenaivoltageimpactsfromBradley90MWoperation.The .PTI analysis (and an update conducted later at.HEA's request)indicates that,if a series of conditions are in place andmaintained,the highest Kenai transmission level voltages resulting from a transmission fault or disturbance are 123 percent of the nominal voltage (115 KV).. HEA was requested to consider the new technical information andrespondtotheotherBradleypurchasersassoonaspossible.Wehaveconcludedourreviewandofferourpositioninthespiritofcooperation.: The 123 percent over voltage exceeds the current maximum limit byapproximately8percent.We continue to believe the currentmaximumlimitisjustifiedandshouldnotbeexceeded.Considering the complexity of the analysis,however,and considering that suchovervoltagesmayoccurinfrequently(less than once or twice peryear),HEA is willing to cooperate with the other:purchaserS"ttivao.00°:.,trial operation of the project which would allow normal schedulinguptotheproposed90MWlevel.The trial period would commenceandcontinuesolongasthefollowingitemshaveibeenagreedto,completed,or are in existence and reliably operating: 1..The Bradley machine with the largest load is automatically tripped off-line for a fault on the Bradley-Soldotna transmission line. 2.All Bradley Lake systems are in-service and completelyoperational,including the digital excitation stabilizers on both machines.; 228 fL9G-TSh 2O6 NOLLYALSINIWGY vane St:Ot Ze peep inmate 9 ama: G2/04/S2 """16 GUEA ADMINISTRATION 98?451-5633 a1 °. :5 °9ARESchSSmyegots,.t f °§ Mc.Kike KellyJanuary27,1 32 :-Page2 3.Protective relaying is provided to automatically trip the *Soldotna capacitors off-line for any fault that would or j could result in islanding of the Kenai.This includes afaultontheSoldotna-Quartz Creek line and the Daves Creek-University line.If the relaying systems are notoperational,all capacitors must be off-line,and normal ; voltages must be acceptable to HEA.: a.The HEA 69 XV transmission line between Soldotna and Quartz Creek is operated normally open (not looped). 5.The Bradley Lake excitation syatemn texting har been completed and all parties are convinced of proper future |operation,as modeled by the PTI studies.[Note:It is } our understandiag Lhal testing vf the exciters has been ' delayed.We will agree to relaxing the voltage swing jcriteriaaslongastestingoftheexcitersproceedsasi currently planned.)., 1 6.All existing Kenai protective relay systcms arc on lincandinreliableoperatingcondition.7.The ben aisturbance system monitor (DSM)located atBerniceLakeison-line,operational,and programmed torecordKenaiaystemvoltage/frequency fluctuations duringdisturbances.HEA shall have access to the output ofthisdeviceimmediatelyfollowingallrelevantdisturbances. 8.Other,HEA voltage recording systems are operational andon-line. In addition to the above system requirements,we will require the : following: 1.HEA shall receive a daily summary of the Kenai systemstatusandoperationsfuseLhepelus24hours,to include:' i i a.A schedule of machines on-line and WATT/VAR :outputs;i b.Hourly schedule of capacitor bank use;and c.Hourly HEA loads. 2.There!are no storms,avalanche conditions,or abnormaltransmissionlinestatuswhichincrearmestheprobabilityofafaultonordisturbanceaffectingtheAnchoragetoSoldotna115Kvtransmissionline. 02-04-92 09:23AM POO!#25 (aris a . @2/84/S2 {71 GUEA ADMINISTRATION 987?451-5633 G2 {. i ! i i } Jacuaryare atata OFPage3 ide All parties aust agree that should any future disturbanceresultinvoltageexceedingthecurrentlimits(115percentofpre-disturbance level),or other undesirable operating characteristics,the trial test will cease andcurrentrestrictionsonBradleywillbeimplementediumediatelypendingevaluationandagreementbyall pertics to resume trial operations. If the other participants agree to the above conditions,HEA willagrestoatemporaryrelaxationofthevoltageswingcriteriaonlyLoalluwintusieupurationoftheBradleyLakeProjectuptothe90MWlimit.By entering into this temporary agreement,HEA does notrelinquishitsjinherentrightstodetermineacceptableoperatingconditionsonitssysten. Sincerely, OCIATION,INC. N.uf St General ManagerNES/Je g : i 02-04-92 09:23AM P0002 #25 TO: FROM: SUBJECT: CHUGACH ELECTRIC ASSOCIATION, Anchorage,Alaska INC. September 15,1992 Dispatchers David W.Burlingame,Manager,Power contro yO Bradley Condensor Mode Change The plant has found an incorrect setting in the Bradley governor which changed it from condense to generate at 59.9 Hz instead of 59.8 Hz.It has been lowered to 59.8 Hz. Please leave a note if it changes state for unknown reasons again. /Routing SlipCHECK-oidBELCHER SLANCEY UNHAM EIGUM i EDOR WUTELLINGSar FYENHOF h_uS ARDELL 6M, STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUE A 'ENGLEWOOD,COLORADO 80111 -2137 ADORESS ALL CORRESPONDENCE TO P.O.BOX $406,DENVER,COLORADO 80217-5406WiROmameom-TEROE ZN PB TE Pr taupenDaLe.Pe b=EOEIIVE Dy micuwouo waSacmeeetu&waenmerow 9 NOV -5 1993 Alesks irdustris;!Development and Exon Authority Mr.D.R.Eberle November 4,1993 Alaska Industrial Development - and Export Authority J.O.No.19239.23 480 West Tudor Rd.;WP 26C Anchorage,AK 99503 ,SWEC/AEA/3002 TRANSFER TRIP STATIC VAR COMPENSATOR SYSTEM BRADLEY LAKEHYDROELECTRICPROJECT The total Bradley Lake plant output of 120 MW can be reached with stable operation after a fault if a transfer trip scheme is utilized.Power Technologies,Inc.(PTI)has recommended in their report,"Final Operating Study”dated September 20,1993,that one unit at Bradley Lake should be tripped when the total plant output equals or exceeds 85 MW for the following outages: Bradley Lake -Soldotna 115 kV line Bradley Lake -Diamond Ridge kV line Soldotna -Diamond Ridge 115 kV line Soldotna SVC (entire device). The recommendation to trip at a total plant output level equal to or in excess of 85 MW covers the prior outage of Daves Creek SVC,in anticipation of a second contingency outage.This output trip level could be increased to 89 MW if the double contingencyconditionsareconsideredtobeanunlikelyevent. The transfer trip scheme is presently in service for the line referenced outages at a 90 MW trip level.Minor changes are required to lower this value to 89 MW or 85 MW.The addition of a transfer trip for the entire Soldotna SVC outage is more complex and requires the use of the existing microwave system. 001613.wpt/BL010 1889 ae YrLL --STONE &'WEBSTER -1989 STONE &WEBSTER ENGINEERING CORPORATION 7677 EAST BERRY AVENUE f\ENGLEWOOD,COLORADO 80111 -2137 ADORESS ALL CORRESPONDENCE TOPO BOX 5406.DENVER,COLORADO 802175406 wo Ri WaagpO TEERENE a7 Pax gee” Mr.D.R.Eberle May 14,1993 Project Manager Alaska Energy Authority J.O.No.19239.23 701 East Tudor Rd. . WP 26C Anchorage,AK 99503 SWEC/AEA/2964 COMMISSIONING TEST REPORT STATIC VAR COMPENSATOR SYSTEM BRADLEY LAKE HYDROELECTRIC PR T Enclosed is a copy of the Commissioning Test Program as performed by ABB and a summary of the testing program.The summary indicates that each test was successful. Two large commissioning test documents are available for review at the offices of AEA. These documents detail the results with charts and graphs of each test. Moat Lit}dn Ted Crd eos Theodore Critikos Project Manager TC/MWG/swg Enclosure cc:TCS members le"t.MV 001337.wpt/BLOOS $89 >STONE&WEBSTER -syeyeeay=- COMMISSIONING TEST RESULTS l.Steady state Performance,Start-up/Shut -down etc. Test Case la,2,3,4a,4b,5,6a,6b,7 (refer to page 12 of HAHT 403 195) The objects of these tests are met. HARMONICS With the SVCs in operation is the total harmonic distortion reduced to approx.60%compared to the distortion with the SVC out of service.Especially the existing 5th harmonic ambient in the network is drastically reduced by the SVC on line. SUBSYNCHRONOUS RESONANCE There was no measurable interaction as subsynchronous resonance between the Soldotna SVC and the Soldotna generator. 2.Voltage Control Step Response Test Case 8a,8b,9,10,10b,lla,11b,11bb,12a, 12b,12bb,12c,1l2ce (refer to page 13,of HAHT 403 195) The objects of these tests are met. All the above performed tests fulfilled the response requirements according to the Contract. The worst case for the voltage controller (weakest system =largest gain)was tested with both SVCs connected to one Bradley unit only.The step was introduced as a setting of a parameter in one of the SVC controllers.The step response showed no critical swinging. 3.Dead Line Start Test Case 13,14 (refer to pages 14,15 of HAHT 403 195) The objects of these tests are met. During the various "dead line start"-tests it was found, that the worst case for the aux.power (and thereby for the SVC)was when using a breaker equipped with a pre- insertion resistor;and this due to the slow raising voltage. During the sequence of testing the control strategy was changed from having the TSC blocked to a forced deblocking of the TSC 500ms after the voltage recovery in order to support the 115kV°voltage and thereby the aux. power meeting the requirement to be able to deadline start the Kenai Peninsula with load. With this revised scheme the SVC is loading to network approx.40 Mvar (inductive)the first 500ms and there after approx.0 MVAr. 4.Control Stability and Coordination Test Case 15al,15a2,15a,15b,15d,16,19,20/21, (refer to pages 14,15 of HAHT 403 195) The objects of these tests are met. Comparing 15al and 15a2 line switching Soldotna -BradleylinewithbothSVCsinautomaticmode/manual mode shows©clearly the damping effect of the power system stabilizer implemented in the SVC. The test-serie 15 line switching (opening the direct line between Bradley Lake and Soldotna)showed the capability of the SVC to fast respond to the change in reactive power flow to make the active power commutation into the Diamond Ridge line stable.At 90 MW out of Bradley Lake approx.80-100%of the SVC reactive power at Soldotna was used transiently .(15a/b-Fla-90). Tripping Bradley Lake (test serie 16)demonstrated the influence of the Power Oscillation Damper (POD) implemented in the SVC control.With 105 MW out of Bradley (before being tripped)the power swinging on the Soldotna-Quartz Creek 115 kV line is damped out within 4-5S with the 115kV voltage at Soldotna kept within a band of +/-0.06pu (ignoring the very first transient) (Test 16-F12b-105-b). Isolating the Kenai Peninsula from the Anchorage area grid by opening the breaker at Daves Creek substation toward Anchorage demonstrated the performance of the voltage controller (The power flow on the Quartz-Creek line drops to zero and therefore no Power Oscillation Damper action except at the dropping edge happens). With 52 MW export out of Daves Creek before tripping the line,the voltage overshoot at Soldotna was approx. 1.22pu and the voltage controller settling time approx. 300ms.(20/21-F2a-50) The 115kV system immunity to a 3 phase fault at Daves Creek substation was tested in serie 15d. The test showed some SVC overshoot after clearing the fault,but this was due to the fact,that Soldotna was sensing the 115kV of both the north and the south bus (north and south bus were split),thereby not recognizing the AC fault as a fault.With the north -and south bus connected the performance of Soldotna SVC will be better (no overvoltage). It was however proved,that with an export of 65MW out of the Kenai Peninsula,the power swinging on the Quartz Creek line was damped out within approx.500ms and the voltage overshoot after the fault-clearing was limited to 1.16pu at Soldotna SVC (expected to be better;see above comments)(Test 15d-Fla-65) |eentleqreloeeaesteetboenealge4%OWDOVEHt19CesWannagoantenes,Slricityteats&PASEAONeatcuceedexeAtoteonabongtagted-.oneUaeabenscaegnnevarallethursContahaaMicecteyEtepererbiactlans,qenescotVeoaeeteneACT)lex:|Socumen no ABB Order No.1-359 257 Alaska Energy AuthorityContractNo.2890156 COMMISSIONING TEST PROGRAM FOR CONTROL,PROTECTION, MONITORING EQUIPMENT AND THE SVC SYSTEMS STATIC VAR COMPENSATOR SYSTEMS SOLDOTNA &DAVES CREEK Bradley Lake Hydroelectric Project Kenai Peninsula RE CO:AS PERC issuec)144 OOO CUSIe die g,»!eusseaT Ott.ress.:Doc.type Forma:|rage [>Cracks 14.2 S52 bY Ud §Cee kits a __|Recot:.:|E |$44 | Cneck.2:"i cs)Der.trom:- Ve Reeasec:(ty St Custer 1 Repiaces:HAHT 403 195 Q200384 P2058 «8.88 {| Svc SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT REVISION INDEX REV.DATE REV.CHAPTER PAGE REMARK REV.BY 1992 @)30June lst issue *Enstedt A 30 Aug 2nd issue Enstedt B 18 Sept 3rd issue Enstedt 1993 Cc 31 Mar AS PERFORMED Kara *Ist issue was not aistributed,it was used as a internal working document Rev.C from 31 March 93 Page 2 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT CONTENTS 1.GENERAL 1.1 Introduction 1.2 Commissioning test objectives 1.3 Preconditions for the Commissioning tests 2.SVC FACILITY COMMISSIONING TESTS Introduction Test objectives Precanditions Test procedure 2.4.1 CHECK OUT TESTS 2.4.2 FUNCTIONAL TESTS&WNHNNNN3.SYSTEM COMMISSIONING TESTS 3.1 Introduction 3.2 Test objectives 3.3 Preconditions 3.4.ENERGIZATION TESTS 3.4.1 Introduction 3.4.2 Test objectives 4.3 Preconditions 4 Test procedure OPERATIONAL AND PERFORMANCE TESTS 1 Introduction 2 Test objectives 3 Preconditions 4 Test procedure Page AMmananua=.hhhbononwonwowoo.)sRev.C from 31 March 93 Page 3.HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 1.GENERAL 1.1 Introduction The Commissioning test program for the control,protection and monitoring equipment is divided into two parts (1)SvC Facility Commissioning Tests (2)System Commissioning Tests The SVC .Eacility Commissioning Tests are the Subsystem tests performed at the site on a fully assembled SVC facility with the main 115 kV breaker open and the System Commissioning Tests are those tests performed with the main circuit breaker closed i.e the SVC bus bar work will be energized the SVC operating and connected to the Kenai Peninsula power system. 1.2 Commissioning test objectives The objectives of the commissioning tests are: -To check that all binary and analog interfaces are correct including cabling according to ANSI C37.20-5.3.4.1 and 5.3.4.4 To verify steady state performance and transient response of the controls -To check the automatic energizing and deenergizing sequences which also includes trip tests -To verify stable control mode transfer between different control modes -To verify control stability and coordination between the two SVC systems during large transient disturbances such as_line switching,SVC switching and generator tripping. -To perform hardware tests showing that redundant components function correctly -To check functions for operating,monitoring,alarms-and event- recording 1.3 Preconditions for the Commissioning tests Before conducting the Commissioning tests the Factory System Tests (Simulator tests)of the control cubicles must be successfully completed . Rev.C from 31 March 93 Page 4 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 2.SVC FACILITY COMMISSIONING TESTS 2.1 Introduction The SvC Facility Commissioning Tests are the Subsystem tests performed on the control,protection and monitoring equipment at the site on a fully assembled SVC facility with the main 115 kv breaker open and SVC not connected to the Power System of Kenai Peninsula. SVC Facility Commissioning Tests is divided as follows: -.Check out test -Functional test 2.2 Test objectives The SVC Facility Commissioning Tests follows the erection of SvC facility by performing check out and functional tests on control,protection and other equipment before the energizing. 2.3 Preconditions The erection of following equipment must be finished: -Cabling -Auxiliary Power -Current transformers,voltage transformers -Circuit breaker,isolators -Thyristor valves with valve electronic -Cooling system of the thyristor valves 2.4 Test procedure 2.4.1 CHECK OUT TESTS Check out test of the Control and Protection cubicles: -Visual inspection of the cubicle -Check installation for completion (acc.to drawings) -Check and tightening the terminal connection -Check grounding -Cable routing -Megger test of all control cables -Continuity test off all control cables from terminal to terminal by electrical circuit tester in accordance with ANSI C37-20-5.3.4.1 Rev.C from 31 March 93 Page 5 HAHT 403 195 the the SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Check out test of the Thyristor valves: -Erection of the fibre optic cables -Measurement of the light efficiency Thyristor level test with a testing transformer -Verification of phase rotation from the valve according to the control drawings Check out of switch yard: -Megger test of busbar work and transformer before energizing. -Tightening of mechanical connections 2.4.2 FUNCTIONAL TESTS Functional test of the Control and Protection cubicles: -Check power supply -Test alarm and trip indications Check gate control -Check valve base electronics -Check PHSC parameters Check PHSC user program timing -Check protection relays and corresponding trip circuits -Perform trip test on main breaker from ESOF button and protection relay -Operational and sequence test of all control cables in accordance with ANSI C37-20-5.3.4.1 and 5.3.4.4 i.e. -CT and PT ratio and polarity check,metering check, relay calibration check on circuits with secondary injection tests -Operation and sequence tests of circuit breaker and isolators Functional test of event recording system: -Check power supply -Test alarm and trip indications -CT and PT polarity check on circuits with secondary injection tests Rev.C from 31 March 93 Page 6 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 3.SYSTEM COMMISSIONING TESTS 3.1 Introduction System Commissioning Tests are those tests performed at the site on each fully assembled SVC facility with the main 115 kV circuit breaker closed i.e the SVC bus bar work will be energized the SVC operating and connected to the Kenai Peninsula power system. During those test,extra caution must be taken to the procedures of energization,communication,and authorisation procedures with the system dispatcher and operating personal.To ensure this must the Purchaser appoint a System Test Coordinator,and clearly establish his role. System Commissioning Tests are divided into: -Energization tests -Performance and Operation tests 3.2 Test objectives The System Commissioning Tests complete the commissioning of the SVC facility by performing following tests: ENERGIZATION TESTS Voltage withstand test -Protective tripping Manual block/deblock Manual Current ramping PERFORMANCE AND OPERATION TESTS -Steady state performance Automatic sequences: -manual block and deblock -start up and shut down -emergency switch off -AC dead line start Transient response Control stability and coordination: -line switching -SVC switching -generator tripping Operator initiated mode changes: -change over between automatic voltage control and manual susceptance setting -local and remote setting of voltage reference Hardware test: -check of redundancy -loss of power suppiies Rev.C from 31 March 93 Page 7 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 3.3 Preconditions The availability of the 115 kV voltage on the bus bars and the successful performance of each individual svc Facility Commissioning Test. The measuring set-up is installed,which is the same as used for the Simulator tests. Two 16 channel UV-recorder with a fixed set of signals and a four channel oscilloscope for the monitoring of important signals for each test,will be installed at each of the SVC stations. For the synchronizing of UV-recorders,oscilloscopes and also for initialization of events like steps in control system or tripping of AC lines etc.a sequencer will be placed in Soldotna station. Rev.C from 31 March 93 Page 8 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 3.4.ENERGIZATION TESTS 3.4.1 Introduction During the Energization tests the SVC components will be connected to the bus voltage of the power system for the first time,so extra caution must be taken to the procedures of energization,emergency procedures,communication,and authorisation procedures with the system dispatcher and operating personal. 3.4.2 Test objectives To show the voltage withstand and the current carrying capability of transformer and each branch of the SVC . 3.4.3 Preconditions Energization tests are performed after completion of individual sub-system and SVC Facility Commissioning Tests The switching instructions must be prepared for each test by the operating personal. Purchaser's system operator must assure that the AC network can absorb or generate the desired MVAr's for each test. 3.4.4 Test procedure A final visual check must be performed before every energizing test to assure that all ground switches are open.safety grounds are removed,removable bus links are re-installed,interlocks are not disabled,and safety precautions are observed. During filter energization,special attention should be paid to the bus voltage monitoring which will indicate the short circuit capacity of the AC system. After each Voltage withstand test a protective tripping test can be performed to switch off the system,if allowed from the Purchaser's system operator personal. Rev.C from 31 March 93 Page 9 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Voltage withstand tests Each component of the SVC facility should be energized one at a time to isolate potential problem areas. Energization of the transformer -Disconnect the thyristor valves and filter branches through the isolators -Energization of transformer -Check the phasing and amplitude of primary and secondary voltages _-/_ Protective tripping -Perform a Protective trip from the ESOF button and by activating a protection relay Voltage withstand tests Energization of the thyristor valves with blocked (unreleased) firing pulses -Firing pulse phase correlation test to the valve voltages Energization of each AC-Filter branch -Measurement of filter rated currents and voltages -Measurement of filter unbalance currents Manual block/deblock -Energization of the thyristor valves with blocked (unreleased)firing pulses -Set the control to manual mode -Set the susceptance to O %,corresponds to zero current -Deblock (release)the firing pulses Manual Current ramping -Manual adjustment of the susceptance from O towards 100% (from zero to rated current) -Measurement of the TCR current under variation of firingangle -Fine adjustment of the gate control Rev.C from 31 March 93 Page 10 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT 3.5.OPERATIONAL AND PERFORMANCE TESTS 3.5.1 Introduction During the Operational and Performance tests switching actions, changes in operating point will be performed and disturbances will be applied in the control-or AC system,so extra caution must be taken to the safety of the power transmission system of Kenai Peninsula. 3.5.2 Test objectives The Operational and Performance tests end the commissioning of the SVC facility so that it can be handed over to the Purchasers operating personal. 3.5.3 Preconditions Operational and Performance tests are performed after completion of the Energization tests.' The switching instructions must be prepared for each test by the operating personal. Purchasers system operator must assure that the AC network can absorb or generate the desired MVArs and that the required system configuration and power levels can be reached for each test,as described in the test sequence. 3.5.4 Test procedure A proposed Test Sequence is presented where the tests are listed in such a way that: -avoid to often changes in system configuration -avoid to often changes in power level -all test which can be performed individually will first be performed in Daves Creek and than in Soldotna station. The requested power levels are the same as used in the simulator test and shows that the generator is connected and which preferablelevelshouldbereached.Power level where var (variable)is stated are levels which can not be fixed yet because they are dependent ontheloadsinthesystem,but must be settled before the start of the commissioning tests. If not stated both SVC are on. For each case 1.1,1.2,....etc a separate Test Procedure is attached.: Rev.C from 31 March 93 Page 11 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Test sequence: Case Test Power:BRAD BERN COOP SOLD D.C. Duration Gen.Gen.Gen.Gen..export la Steady state performance 60MW 25MW off off var 3x8h Daves Creek Soldotna SVC is off 2 C2b Start up and shut down,60MW 25MW off off var 4h Daves Creek Soldotna SVC is off 3 C3b Emergency switch off,60MW 25MW off off var 4h _-Daves Creek Soldotna SVC is off 4a Steady state performance 60MW 25MW var off var 3x8h Soldotna Daves Creek SVC is off 4b Steady state performance 60MW 25MW var var var 2x8h Soldotna Daves Creek SVC is off # 5 Cl First Aut.block and 60MW 25MW off off var 4h deblock,TSC Soldotna Daves Creek SVC is off 6a C2a Start up and shut down,60MW 25MW off off var 4n Soldotna Daves Creek SVC is off 6b C2a Start up and shut down,60MW 25MW off var var 2h Soldotna Daves Creek SVC is off # 7 C3a Emergency switch off,60MW 25MW off off var 4h Soldotna Daves Creek SVC is off #=additional test requested bv the customer Rev.C from 31 March 93 Page 12 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Case Test Power:BRAD BERN COOP SOLD D.C. Duration Gen.Gen.Gen.Gen...export ; 8a D2 Volt.Ctrl step resp.60MW 25MW off off var |8h strong syst.Soldotna Daves Creek SVC is off 8b R2 Volt.Ctrl step resp.60MW 25MW off var var 2h strong syst.Soldotna Daves Creek SVC is off # 9 b4 Voltage Ctrl step 60MW 2SMW var off var 8h response,Daves Creek Soldotna SVC is off 10 DS Voltage Ctrl step 60MW *OMW off off var 4h response,trip Bernice gen.1LOMVAr 10b BS Voltage Ctrl step 60MW *OMW off off var 4h response,trip Bernice gen.SMW +1OMVAr lla RL Volt.Ctrl step resp.45MW off off off var 8h weak syst.Soldotna Daves Creek SVC is off 1lb RL Volt.Ctrl step resp,45mMw off off off off 8h weak syst.isl.Soldotna Daves Creek SVC is off # llipbb Dl Volt.Ctrl step resp,45MW off off off off 8h weak syst.isl.Soldotna Daves Creek SVC is ON 12a D3 Voltage Ctrl step resp.45MW off off off var 8h weak syst.Daves Creek Soldotna SVC is off 12b D3 Voltage Ctrl step resp.4SMW off off off off 8h weak syst.isl.Daves Creek Soldotna SVC is off # i25b 23 Voltage Ctrl step resp.45MW off off off off 8h weak syst.isl.Daves Creek Soldotna SVC is ON 12c D3 Voltage Ctrl step resp.4S5MW off off off off 8h weak syst.isl.Daves Creek Trip Soldotna SVC is Manual Mode l2cc D3 Voltage Ctrl step resp.45MW off off off off 8h weak syst.isl.Soldotna Trip Daves Creek SVC is Manual Mode . Rev.C from 31 March 93 Page 13 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Case Test Power:BRAD BERN COOP SOLD D.c.| Duration Gen.Gen.Gen.Gen..export : 13 Begin AC dead line start OMW OMW OMW OMW OMW 8h tests from Anchorage 14 Begin AC dead line start OMW*OMW OMW OMW OMW 8h from Bradley 15al Ela Line switching SOMW 25MW off off var 12h Soldotna-Bradley line Both SvCs in automatic control 15a2 Ela Line switching SOMW 25MW off off var 12h Soldotna-Bradley line Both SVCs in manual control 15a Ela Line switching 60MW 25MW off off var 12h Soldotna-Bradley line 8O0MW 25MW off off var# SOMW 25MW off off var# 15a Ela-T Line switching SOMW 25MW off off var# 12h Soldotna-Bradley line and L1I6MW 25MW off off varF Trip one of two Bradley Gen. 15b Ela Line switching 60MW off off off var # 12h Soldotna-Bradley line 80MW off off off var # 90MW off off off var # 15b Ela-T Line switching 1L1ISMW off off off var # 2h Soldotna-Bradley line and Trip one of two Bradley Gen. 15d Fla Line fault 3SOMW off off off 25MW # 8h 3 phase Fault at Daves Creek 75MW off off off 65MW # 16 Fl2b Generator trip *6O0MW 45MW off off var 3x8h trip Bradley *60MW off off off var # *BOMW 45MW off off var # *9OMW 45MW off off var # *1OSMW 45MW off off var # 19 Elib Generator.trip 60MW *10MW off off var 4h trip Bernic(open $1) *=one generator #=additional test requested by the customer Rev.C from 31 March 93 Page 14 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Case Test Power:BRAD BERN COOP SOLD D.C. Duration Gen.Gen.Gen.Gen..export 20/21 E2a Line opening,isolation 25MW OMW 16MW off 10MW # 2H at Quartz Creek 20/21 E2a Line opening,isolation 4x8n line D.C.-Portage 60MW off off off 25MW 85MW off off off SOMW & 14 Begin AC dead line start OMW*OMW OMW OMW OMW 8h from Bradley with TSC 22 Trial operation for var var var var var 6x8h Soldotna and Daves Creek #=additional test requested by the customer Rev.C from 31 March 93 Page 15 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase1 Case Test Power:BRAD BERN COOP SOLD 0D.C. Gen.Gen.Gen.Gen..export la Steady state performance 60MW 25MW var off var 3x8h Daves Creek Soldotna SVC is off Set the control to Manual mode Energize the SVC Change the control to Automatic mode /voltage control Raise and lower the system voltage ,to show V/I characteristics Verify: -Control accuracy +/-1% -Firing pulse asymmetry -Slope characteristic adjustable locally and remote from 1 to 5 %(linearity). -Voltage reference setting adjustable locally and remote -Susceptance output limiter controller -Harmonic content throught measurement TestprocedureCase2 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen...export 2 C2b Start up and shut down,60MW 2S5MW off off var 4n Daves Creek Soldotna SVC is off - Start automatic start up and shut down sequence on the local mimic -Start automatic start up and shut down sequence remote TestprocedureCase3 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 3 C3b Emergency switch off,60MW 25MW off off var 4h Daves Creek Soldotna SVC is off -Initiate the Emergency switch off on the mimic in Daves Creek -Start automatic start up down sequence on the mimic Rev.C from 31 March 93 Page 16 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase4 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 4a Steady state performance 60MW 25MW var off var 3x8h Soldotna Daves Creek SVC is off 4b Steady state performance 60MW 25SMW var var .var 2x8h Soldotna Daves Creek SVC is off Set the captrol to Manual mode Energize the SVC Change the control to Automatic mode /voltage control Raise and lower the system voltage ,to show V/I characteristics Verify: Control accuracy +/-1% Firing pulse asymmetry Slope characteristic adjustable locally and remote from 1 to 5 %(linearity) Voltage reference setting adjustable locally and remote Susceptance output limiter controller Harmonic content throught measurement TestprocedureCase5 Case Test Power:BRAD BERN COOP SOLD 0D.C. Gen.Gen.Gen.Gen..export 5 Cl First Aut.block and 60MW 25MW off off var 4h deblock,TSC Soldotna Daves Creek SVC is off SvC is energized from previous case Change the setting of the voltage control for a slower response Apply a step change in the voltage measurement so that the SVC will change to more capacitive,switching on the TSC and on the same time compensate with the TCR. Remove the step change in the voltage measurement i.e.the TSCwillbeswitchedoff Rev.C from 31 March 93 Page 17 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase6 Case Test Power:BRAD BERN COOP SOLD D.C.. Gen.Gen.Gen.Gen...export 6a C2a Start up and shut down,60MW 25MW off off var 4h Soldotna Daves Creek SVC is off 6b C2a Start up and shut down,60MW 25MW off var var 2h Soldotna Daves Creek SVC is off -Start automatic shut down sequence on the mimic -Start automatic start up down sequence on the mimic TestprocedureCase7 Case Test Power:BRAD BERN COOP SOLD D.C. exp.export 7 Cia Emergency switch off,60MW 25MW off off var 4h Soldotna Daves Creek SVC is off -Initiate the Emergency switch off on the mimic in Soldotna -Start automatic start up down sequence on the mimic TestprocedureCase8 Case Test Power:BRAD BERN COOP SOLD OD.C. Gen.Gen.Gen.Gen..export 8a R2 Volt.Ctrl step resp.60MW 25MW off off var 8h strong syst.Soldotna Daves Creek SVC is off 8b R2 Volt.Ctrl step resp.60MW 25MW off var var 2h strong syst.Soldotna Daves Creek SVC is off Perform a step change in the line voltage (delta VLine)in the PHSC at Soldotna SVC . Monitor the step response in Soldotna Rev.C from 31 March 93 Page 18 HAHT 403 195 SVC SOLDOTNA &DAVES CREEKCOMMISSIONINGTESTPROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase9 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 9 D4 Voltage Ctrl step resp.60MW 25MW var off var 8h strong syst.Daves Creek Soldotna SVC is off -Perform a step change in the line voltage (delta VLine)in the PHSC at Daves Creek SVC -Monitor the step response in Daves Creek -_ - Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen...export 10 RS Voltage Ctrl step resp.60MW OMW*off off var 4h trip Bernice gen.LOMVAr +or - *«©one generator -Trip Bernice generator Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 10b DS Voltage Ctrl step resp.60MW SMW*off off var 4h trip Bernice gen.1OMVAr +or - *x *one generator -Trip Bernice generator TestprocedureCaseil Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export ila Dl Volt.Ctrl step resp.45mMw off off off var 8h weak syst.Soldotna Daves Creek SVC is off 11b Rl Volt.Ctrl step resp,45mMW off off off off 8h weak syst.Soldotna Daves Creek SVC is off -Perform a step change in the line voltage (delta VLine)in the PHSC at Soldotna SVC -Monitor the step response in-Soldotna Rev.C from 31 March 93 Page 19 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase12 Case Test Power:BRAD BERN COOP SOLD 0D.C. Gen.Gen.Gen.Gen..export 12a R32 Voltage Ctrl step resp.45MW off var off var 8h weak syst.Daves Creek Soldotna SVC is off 12b D3 Voltage Ctrl step resp.45MW off var off oft8hweaksyst.isl.Daves Creek Soldotna SVC is off Perform a step change in the line voltage (delta VLine)in thePHSCatDavesCreekSVC -Monitor the step response in Daves Creek Rev.C from 31 March 93 Page 20 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase13 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 13 Begin AC dead line start OMW OMW OMW OMW OMW tests from Anchorage SWITCHING SEQUENCE:switch-position: S2a S2b SVC S4 S5 SVC S6 5S§20 -Step Sold D.C. 1 Op Op Cl Cl Op C1 Cl Cl CS Dead line start,Sold.5 x x Cl x x x 6 x Op x x x x C6 Dead line start,Sold.7 x cl x x x x 8 x x Op Op x x CZ Dead line start,Sold.9 x x cl x x 10 x Op x x x C8 Dead line start,Sold.11 x Cl x x x Open the switch Close the switch The switch was closed in a previous stepe)ror)weaFor the switch designation Sl to "DIAGRAM:NETWORK CONFIGURATION Rev.C from 31 March 93 S20 see next page (in the Simulator Set-up)" Page 21 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK 'COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT Description of the models (in the Simulator Set-up): Bernice Lake generator,1 model of two generators 0 -60 MW transformer,switchable l or 2 Bradley Lake generator,1 model of two generators O -120 Mw or 1 model of one generator O -60 MW transformer,switchable 1 or 2 Cooper Lake generator,1 model of two generators O -16 MW $11,84,S5 and S6,are circuit breaker models (thyristors, the current will extinguish at next zero crossing) Anchorage equivalent,maximum short circuit power S20 Closed minimum short circuit power S19 Closed SOLDOTNA DAVES CREEKSTATIONSTATION azenef.Sid (yn QUARTZoneeDen_7 CREEK two cicsed on/off $1 en/ort-3°ayy -meWO==ih HAS PORTAGE SERNICE DeLAKE. COOPER 315 $12 $10 LS L4 7 }--Le $20 wronmsf.Sié $11 $4 Sant rent S5 one eden Ld wo ciosed 4 on/off $35 Fl $30 ; -32 'erat |7e00t L "CO-o4EHEE tH 7 UNIVERSITY F2SRADLEYDIAMONDLAK=RIOG= -$25 we S2e $3rL}-=-TH +836SEWARD F4on/off on/off LH cL}as318/26 azsus svc svc Rev.C from 31 March 93 Page 22 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase14 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 14 Begin AC dead line start OMW*OMW OMW OMW OMW from Bradley *=one generator SWITCHING SEQUENCE:switch-position: S2a S2b SVC S4 S5 SVC S6 $20 _- Step Sold D.C. 1 Op Cl Cl Op Op Op Op Op C9 Dead line start,Sold.3 Cl x x 4.x Op x C10 Dead line start,Sold.5 x cl x 6 x x x cl Cl Cll Dead line start,D.C.7 x x x x Cl x 8 x x x Op x x C12 Dead line start,D.C.9 x x x Cl x x 10 x Op Op x x x C13 Dead line start,D.C.11 x cl x x x Op =Open the switch Cl =Close the switch The switch was closed in a previous step For the switch designation Sl to S20 see previous page"DIAGRAM:NETWORK CONFIGURATION (in the Simulator Set-up)" Rev.C from 31 March 93 Page 23 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK 'COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase15a The aim by these tests will be to seek for the highest power export level to the Anchorage area during switching off the Soldotna- Bradley line. Case Test Power:BRAD BERN COOP SOLD OD.C. Gen.Gen.Gen.Gen..export 15al Ela Line switching SOMW 25MW off off var 12h Soldotna-Bradley line Both SVCs in automatic control 15a2 Ela'-Line switching 5OMW 25MW off off var 12h Soldotna-Bradley line Both SVCs in manual control 15a Ela Line switching 60MW 25MW off off var 12h Soldotna-Bradley line 8OMW 25MW off off var# SOMW 25MW off off var# 15a Ela-T Line switching SOMW 25MW off off var# 12h Soldotna-Bradley line and 116MW 25MW off off var# Trip one of two Bradley Gen. -Trip and close the breaker on the line to Bradley lake in Soldotna Station for each power level TestprocedureCase15b The aim by theese tests will be to seek for the highest power export level to the Anchorage area during switching off the Soldotna-Bradley line,when the Bernice lake generators are off line. Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 15b Ela Line switching 60MW off off off var # 12h Soldotna-Bradley line 80MW off off off var # 9OMW off off off var # 15b Ela-T Line switching L15MW off off off var #£ 2h Soldotna-Bradley line and Trip one of two Bradley Gen. -Trip and close the breaker on the line to Bradley lake inSoldotnaStationforeachpowerlevel Rev.C from 31 March 93 Page 24 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK "COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase15¢ TestprocedureCase15d Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 15d =Fla Line fault 3OMW off off off 25MW # 8h 3 phase Fault at Daves Creek 75MW off off off 65MW # -Apply a three phase fault on the Daves Creek 115 kV line -No reclosure! TestprocedureCase16 Case Test Power:BRAD BERN COOP SOLD 0D.C. Gen.Gen.Gen.Gen...export 16 Fl2b Generator trip *60MW 45MW off off var 3x8h trip Bradley *60MW off off off var & *80MW 45MW off off var # *O9OMW 45MW off off var *1lOSMW 45MW off off var ; *=one generator -Trip Bradley generator at each power level Rev.C from 31 March 93 Page 25 HAHT 403 195 Svc SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase19 Case Test BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 19 Ellb Generator.trip 60MW *1OMW off off var trip Bernic(open S1) Trip Bernice generator Rev. _- C from 31 March 93 *=one generator Page 26 HAHT 403 195 SVC SOLDOTNA &DAVES CREEK COMMISSIONING TEST PROGRAM CONTROL,PROTECTION AND MONITORING EQUIPMENT TestprocedureCase20/21 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..export 20/21 E2a Line opening,isolation 25MW OMW 16MW off 1OMW # 2H at Quartz Creek 20/21 F2a Line opening,isolation 4x8h line D.C.-Portage 60MW off off off 25MW 85MW off off off SOMW # -Trip the breaker on the line to Portage in Daves Creek Station Close the breaker on the line to Portage in Daves Creek Station 14 Begin AC dead line start OMW*OMW OMW OMW OMW 8h from Bradley with TSC TestprocedureCase22 Case Test Power:BRAD BERN COOP SOLD D.C. Gen.Gen.Gen.Gen..expor 22 Trial operation for var var var var var 48h Soldotna and Daves Creek Rev.C from 31 March 93 Page 27 HAHT 403 195 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska November 15,1991 TO:TCS Members FROM:David W.Burlingame,Secretary SUBJECT:October 31,1991,TCS Meeting Minutes Below are the draft meeting minutes for the above referenced meeting. The previous meeting minutes were approved. SVC Contract -ABB is in Anchorage and is meeting with AEA,HEA and Chugach to determine the interface points for the control and relaying systems.The SVC is due to be operational March 4,1993.ABB will use CEA standard drawing numbers.The AEA drawing numbers will be included on the sheets as a reference. The following motion was unanimously approved: Motion -Move to add a filter breaker at Daves Creek station and delete the UPS systems at Daves Creek and Soldotna. Bradley Lake Dispatcher Guidelines -Brief comments were made on the guidelines distributed by SWEC.The guidelines outline the plant characteristics,operating modes, alarms and callout procedures,etc.Comments are due Friday,November 8,1991. Kenai Operating Guidelines -PTI presented the results of the requested studies regarding the Kenai export and/or Bradley output guidelines.The committee unanimously agreed the study results presented by PTI appear to reasonably outline the operating limits intended by the TCS. The committee clarified the voltage deviation criteria to note that the maximum voltage deviation of 115%was a deviation from predisturbance voltage levels and not the nominal voltage levels.In the submitted study,PTI used the 115%limit to be the limit of voltage rise from the nominal system voltage.The predisturbance voltage on the system ranged from 1.04 to 1.048.The maximum change of voltage noted in the study as the 120%limit, is actually equal to or less than the 115%criteria. The committee determined the risk of damage due to low voltage levels following faults on the Quartz Creek -Soldotna 115 kV was less than the problems associated with islandingtheKenaisystemshouldthe69kVcircuitbecrosstrippedtopreventthelowvoltages.Inviewofthereliabilityofthe115kVline,the committee agreed to not cross trip the 69 kV 2) October 31,1991,TCS Meeting Minutes Page 2 circuit for export levels below the previously established limit by PTI and not restrict theKenaiexportforfaultsonthislineandthecorrespondinglowvoltagesafterthefaulthas -been cleared. The committee discussed that the concept of probabilistic transmission reliability.The basicconceptbeingthereliabilityofthetransmissionsystemandtheprobabilityofassociated-transmission disturbances would be evaluated against the likely cost of equipment or consumer damage. The Committee unanimously adopted the following motion changing the high voltage criteria. 'Motion -Move to adopt an interim voltage criteria until the SVC systems are operational to not allow voltage levels above 110%of their predisturbance levels for more than approximately 1 second. 'The following motions were unanimously adopted to outline the guidelines under which Bradley Lake and the Kenai are to be operated: Motion -Move that operating guidelines for Bradley Lake and the Kenai Peninsula governed by voltage criteria shall be based on the Table 1S1 of the PTI study,listed as the 120%voltage criteria. Motion -Move that operating guidelines for Bradley Lake and the Kenai Peninsula governed by the stability criteria shall be that defined in Table 1S1.The plant shall be scheduled such that the MW loading of unit No.1 will be at least 1/2 of the total plant output. Motion -Move to install cross-tripping on both generating units at Bradley Lake to trip unit #1 for a line fault on either the Bradley Lake -Soldotna or Bradley Lake -Diamond Ridge transmission line. The committee unanimously adopted the following motion to enable the PTI study results to be forwarded to the Operations and Dispatch Subcommittee: Motion -Move to adopt the results of case scenarios C1A,C1B,C2A,C2B,F1A,F1B,F2A and F2B as set forth in table 1 of the PTI study and as defined by present voltage and stability criteria,including the use of unit tripping. The committee requested PTI run load cases D &E as defined in the original study with both summer and winter loads.The committee approved the issuance of these cases to the October 31,1991,TCS Meeting Minutes an Page 3 O&D subcommittee to be used until final approval at the next TCS meeting.The cases will be presented as table 2S1.The committee unanimously approved sending these additionalcasestotheO&D Subcommittee upon their completion. The committee clarified that these tables are guidelines to be used in the normal operationofthesystem.Abnormal or emergency conditions may deviate from the guidelines onacase-by-case basis.gy The committee unanimously approved the following motion with respect to total capacityofBradleyLake:Ei Motion -Move to restrict the scheduled energy plus capacity output of Bradley LLake to 90MWorbelow.tee, The TCS unanimously approved the following motion regarding the installation of hot-stand-by on the State microwave systems between Soldotna and Bradley Lake.The costs would be considered part of the project costs required to bring the reliability of the State microwave up to utility standards. Motion-Move to install hot stand-by on the systems which do not currently employ themontheStatemicrowavesystembetweenBradleyLakeandSoldotna. The committee moved to table the discussion on the Kenaiimport study until the next TCSmeeting.:oe 307.DWB DWB/mel Attachment:Attendance list Distribution:S.Haagenson -GVEA ve tempi a7 M.Aslam -ML&P ayo cd ah ty J.Hall -MEA S.Matthews -HEA M.Yerkes -FMAA D.Calvert -SES D.Eberle -AEA File 410 LLFt,(PL.Lape Jes AFT RNO ECS Lavi!Goctny oe STEVEN sdbGiteiso) Seaoey Evans za Sears Jin Met ( Noe (petamn Tiny,MN Counell )Toave Coacverr Line ZEKE [ce fin Cuceofe for? John Vale Jown Dn uon4 Ae. ce/7 GuéA fata Jat /leo LAEL- MLLP LAL? SES TS 'sS frCOPY:freGrbEed©CHUGACH ELECTRIC ASSOCIATION,INC.it?A Anchorage,Alaska M A 5 Fa October 8,1992 It Antid? Os Bradley Lake PMC ROM:David W.Burlingame,TCS Secretary UBJECT:TCS Meeting Report he following is a synopsis of the TCS meeting held on October 8, 992. 'CADA SubCommittee has reviewed the DECNET installation at Bradley ake.SWEC is waiting for the final points list to be received 'rom Golden Valley and AML&P prior to implementing.SWEC has'equested Landys &Gyr investigate alternative methods of supplying[EA with requested information other than the present design. ivc Project Status -The transformers at both sites are installed, 'eactors installed,switches and buswork installed and the valves ire on-site.The Daves Creek SVC is tentatively scheduled to be ;ecteg to the power system October 16,1992.The Svc is not|daled to begin any testing until November. jradley Lake Water Elevation -The water elevation is downsignificantlyandprojectallocationsareexpectedtobeadjustediownward.SWEC/AEA found an error in the field survey whichresultedinthewaterelevationatthedambeingreported2'lower than it actually is. svC Simulator Studies -SWEC presented an analysis of the analog and digital simulator studies ABB performed at AEA's request.The studies were performed due to the apparent discrepancy between the stability numbers found by ABB in their initial tests and the PTInumberswearecperatingunder.The utilities objected to the SWECconclusionasSWECwasusingnumbersfromasupersededPTIstudyandthenotthenumberscurrentlyinuse.SWEC will investigatefurther.SWEC was requested to run an additional case to ascertainthestabilitylimitaftertheSvc's are installed as this now appears to be in question. Kenai Oscillations -SWEC presented its findings an the cause oftheKenaioscillationsandtherecommendedshorttermsolutions.The committee accepted two of the recommendations with motions as follows: matically as soon as possible via Chugach's SCADA control upon awection of islanding to prevent or mitigate Kenai frequencyoscillations. on 1 -Move to put one Bradley Lake unit in deflector The above action has previously been implemented by Chugach andaccordingtotheSWECstudies,should prevent oscillation duringthosetimeswhentheKenaiisexportingmorethan10MWofpower. Motion 2 -Move to disable the gain acceleration function within the Bradley governor to allow more time before the needle valve and deflectors equalize and begin the Kenai system frequency oscillations.; The above action will be implemented by SWEC as soon as possible. The only detriment to the above is a small amount of water that is wasted on overfrequency conditions since it slows down the time it 'takes for the needles to close and match the deflectors,ie theunitsarerunningontheirdeflectorsforaslightlylongerperiod of time. The committee has not been able to identify any short termsolutionswhichmitigatetheKenailoadsheddingduringimportconditions.SWEC estimates that any import more than 5 MW willresultintotalKenailoadshedding. SWEC was asked to investigate the possibility of automaticallytrippingaunittodeflectorcontrolonoverfrequencyasopposedtowaitingforSCADAcontrol.This may help the Kenai avoid furtherloadsheddingduringimportconditions. SWEC recommended disabling AGC control for Bradley Lake duringtransientperiodimmediatelyafterislanding.Chugach willinvestigateandimplementifpossible. SWEC will investigate the possible long term solutions includingtheinstallationofanewgovernorcontrolmodeatBradleyLake,new intertie,batteries,surge tanks etc.