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HomeMy WebLinkAboutBradley Documentation Review 1988 1governo:mary table Trswo7 T Meeting whether the combination of the Fuji and minutes Woodward contro!systems can function as modeled by PTI.SWEC agreed. 97/89-03-10 |TCS TCS reviewed the PT!report and agreed meeting the report did not justify the minutes recommendations;recommended the report be corrected to address issues listed in minutes 8189-03-16 IPTI-APA [Outlines the new "two”brake solution and Letter PTI stabilizers on units,use of PTI DSM to trigger brakes 12/89-03-22 |\Woodward Torque Vs Speed curves Cover fetter indicates these are letter to not the final curves SWEC 7|89-03-30 [TCS The ability of the Woodward governor and |PTI's first presentation of their Meeting the Fuji deflectors to operate as modeled [proposed brake and series cap Minutes by PTI were questioned;TCS objected to jsolution;TCS reaffirmed its large frequency and voltage swings voltage and Hz criteria;AEA allowed by PTI;Woodward to supply gov _jdirects PTI to complete studies model eeePage 3 :7 89-03-30 governor history table TCS need minutes of Woodward meeting SWEC,Woodward and PTI to resolve meeting minutes modeling differences 13/89-06-01 |Chugach References TCC meeting of 6/1/89 &need TCS meeting minutes of memo Woodward is having trouble meeting 6/1/89 contract spec for stability 9189-07-17 TCS SWEC distributed governor stability study Stability plots &Summary Meeting plots,including a summary;System missing from minutes Minutes damping out of specs 102/89-10-05 |PTI trip synopsis of a meeting between PT!and report TCS,Meeting topic was how faster governor times could avoid loadshedding. good discussion,precursor of surge tank Study 94/89-10-05 |TCS Meeting agenda has the governor factory meeting tests on the agenda minutes Page 4 1/10/97 governc _ry table 'DE DATE|P NAMES te"DESCRIPTION?103/89-12-13 TCS Handout lists the stability criteria usedinMeetingtheinitialsystemstabilitystudies;criteria handout fairly vague 107|89-12-13 INRECA Paper outlines requirements for power Power quality.used by the TCS in setting Quality voltage limits Paper 1489-12-13 |TCS SWEC recommended going to6 needle (TCS recommended tripping to 6 Meeting operation on UF;Water Wasting mode at jneedle mode on under Hz and minutes same instant also tripping to deflector on under Hz.Can't find discussion at to why it was not done. 119/89-12-14 [Kenai Kenai Export Study defined secure and _|Need to obtain study from Export Study emergency export conditions,TCS Chugach requested clear definitions on export limits for Kenai 2690-01-17 ITCS SWEC presented new logic and control _flogic &control diagrams not meeting diagrams for a 3rd control mode for the _included in minutes minutes governor,TCS approved Page 5 Sesirgy wan se governor history table AOS UOATED (UN,i DESCRIPTION” 7 NOTES? 101190-01-18 [PMC SWEC gives n of the Meeting results of the surge tank study which is minutes reflected in the meeting minutes 1590-01-18 [Chugach Memo outlines Bradley governor mode Memo modification; 51/90-03-06 SSWEC FAX |SWEC makes recommendation on These two faxes were not found to AEA deflector control mode &reviewed Woodward's proposal;two faxes;3/6 & 3/7;recommended use of droop other than needle position when in deflector 20)90-04-19 SWEC Load acceptance report;Effective needle |Check when 6 needie mode was Report opening time -72 sec;Study assumes all ladded 6 needles open simultaneously,mode will have to be added 21/90-04-19 |SWEC Load acceptance report;During all Kenai |Report states Bradley is a0 Report import conditions,Kenai will collapse droop governor on water wasting following separation;full offload by . deflectors within 1.5 sec Page 6 1/10/97 governc...._.ory table AOTEGATE:2.NAME?> 52/90-05-23 |[SWEC FAX to AEA design,recommended to eliminate feed forward control of needles 53)90-07-02 |ISWEC Fax _jonly slight decrease in frequency when to AEA feed forward is eliminated;recommended a closer deflector position than proposed 54/90-07-03 |SWEC Fax Analysis of Woodward deflector proposal to AEA 55/90-07-06 |SWEC Fax /|Analysis of eliminating feed forward to AEA control but with increased PID gains 2490-07-09 ISWEC SWEC states that all three Bradley Letter to governor modes will not be studied since AEA they play no rote in the dynamics during and following a disturbance Page 7 ciety Pantumennata recy 18 90-07-12 AMSWECletter governor history table Letter states PTI solutions are very to AEA complicated,require sophisticated o&m and are of questionable reliability;series caps a last resort 19|90-07-17 |Chugach Fuji PSS accepted on the condition that Memo no capacity degradation 17|90-07-19 |TCS Fuji AVR block diagram;Fuji PSS need meeting minutes,we have Meeting description;material from meeting but not minutes meeting minutes of the actual meeting 22\90-07-20 |TCS report |SWEC recommended against series caps ineed TCS meeting minutes of to the PMC |7/19/90;7/19/90 2590-09-11 TCS SWEC recommends against the braking meeting resistor minutes of 8/30 Page 8 1/10/97 governo.....ury table NAME DESCRIPTION:>i SWEC letter SWEC agrees with PTI's recommendation to AEA that a braking resistor is not a good solution 29)90-09-19 TCS SWEC recommends against series caps; Meeting recommended to accept SWEC'sminutesrecommendationforanalogstabilizer conditioned on that there would be no performance degradation 28/90-09-20 ITCS report |SWEC recommended against series caps to PMC due to concerns over SSR 90)90-09-21 PMC SWEC recommends against series caps Meeting and braking resistor Minutes 93/90-10-15 [PTI letter to |Bradley Lake Stabilizer options. SWEC Compares PTI's PSS with a "typical" electrical power input stabilizer; Recommends PTI stabilizer to SWEC Page 9 governor history table FIDESOATE![eC NAME?: IPTION E2300-10-1 5 PTI report to |PTI recommends the use of their PSS PTi made recommendation wio SWEC over the Fuji due to increased Bradley Fuji or GE models;SWEC capacity and performance forwarded to AEA 10-22-90 with agreement 105190-10-22 |SWEC letter |SWEC reevaluates the installation of a to AEA braking resistor at the direction of the PMC.Formally recommends against its installation 30/90-10-25 |TCS SWEC recommends against braking meeting resistor,recommends PTI stabilizer minutes 91|90-11-26 |TCS report |Synopis of braking resistor applications to PMC and reasons for not installing;Digital stabilizers recommended by SWEC;two SVC system recommended 34!91-03-00 \Woodward (Woodward IEEE paper on originally IEEE paper [proposed governor design,paper outlines original control theory Page 10 1/10/97 governo......2ry table HID}DATE:|SNAMI DESCRIPTION 31/91-04-03 |TC TCS approved synchronous condenser meeting mode to be installed minutes 109/91-05-03 |PTI letter to iPTI explains why their model can't AEA duplicate the loadshedding event of 8/29/90,discusses methods used to overcome program 104/91-05-13 JAML&P Tom Stahr cites two IEEE papers on the letter to AEA |bradley governor,states that ML&P nor any other utility should be expected to pay for operating a gas turbine on the Kenai 38/91-06-13 |PTI letter to [Kenai import study -Study determines AEA maximum import levels by assessing how low frequency will drop,does not model UF relay action and corresponding governor action 108/91-07-02 joint Both HEA and CEA GM's sign letter to HEA/CEA _|PMC stating conditions under which a gas letter turbine will be run on the Kenai.If a gas turbine is required following the cmpletion of Bradley,neither HEA or CEA will be responsible for the costs of operation Page 11 governor history table :NAME_ PTI Letter to SWEC MW water wasting,maximum load acceptance is estimated at 23 MW per unit in deflector mode 106/91-07-25 |Chugach Memo provides a summary of the memo problems encountered with the Bradley Governors,focuses on the needle transition problem 33/91-07-25 iChugach During testing of Bradley units,the exciter memo went unstable and although a fix was implemented,PTI was never able to recreate;control mode was eliminated? 41/91-07-25 (Chugach Expressing concern that PTI's studies did [Good record of oscillation Letter to not reflect the system disturbance of between Kenai and Anchorage AEA 7/20/91;exciter went unstable and frequency decayed to 59.23 as opposed to PTI predicted 59.52;Oscillations between BLPP and Anchorage 40/91-08-14 |PTI letter to |Exhaust temperature limitations of the PTI Chugach model will not give accurate results Page 12 1/10/97 govern:sory table HIBS)DATES |NAME DESCRIPTION:OTE 3991-08-14 |PTI fax to ||PTI had to block response of Beluga 6,7 &|Doudna wrote another long letter Chugach 8 since their model could not simulate on 7/12 (?)outage explaining temperature limits how they had to fool the system on North Pole due to a similar problem.is problem still there? 3591-09-00 JSWEC Summary of Bradley Lake commissioning TEST tests;2 relay interface modules to the REPORT __/governor failed;Full load rejection due to interaction with BLPP exciters,stabilizers installed and did not repeat;deflectors rejected 60 MW in 1.5 sec page 9 36/91-09-90 ISWEC 3 needle operation deleted due to severe TEST load swings during needle transitions (20 REPORT |MW): 62/91-10-31 |TCS TCS adopted new voltage criteria to be meeting used for Bradley Lake,criteria is outlined minutes as Table 1S1 of the PTI Kenai export study 32/91-11-20 ISWEC Block diagram of governor control Diagram is hand drawn and Letter to doesn't look final,it is attached to AEA letter but not referenced in the letter and is not dated Page 13 1,wel cprmerges ea governor history table aa teaIESCRIPTION91"an00sie sown "The projectfiles do not contain any documenation to/from PTI/Woodward on the development of original governor model.Is there any?What about subsequent modifications?model We may just have to copy all of the non-fiscal correspondence between Woodward and SWEC/PTI. correspondence? 100/91-8-15 |TCS Deflector mode approved with 15 MW of Meeting water wasting/unit;gov mod to shut unit Minutes down in 100 seconds as opposed to 1.2 following a temp alarm 59/92-01-27 |HEA letter j|HEA outlines the conditions under which to all railbelt |HEA will allow Bradley to operated under utilities the voltage and reliability criteria proposed by GVEA/AML&P and Chugach 111/92-02-13 |CEA letter |Chugach's response to HEA's letter of to HEA 1/27/92;agrees to conditions gives status of recommendations and outlines responsibilities 64|92-02-24 |Fuji exciter [Exciter tests were performed to determine |Request reports if prepared? tests the frequency dependence of the Fuji exciter,it was learned the frequency deviation was due to PTI's DSM;did SWEC ever issue a report on the actual tests?Block diagrams? Page 14 1/10/97 governc...._ory table PTi letter to |Explanation of the PTI DSM's frequency AEA skew and recommended correction 6592-04-21 |TCS PTI explained exciter tests and the Meeting sequence used to find the errors in the minutes of (DSM; 4/13/92 112/92-06-11 |PTI letter to |PTI performs an analysis of the system CEA Voltage collapse 113/92-06-12 |PTl letter to |Establishes the limit of operation w/o the CEA Fritz Creek to Diamond Ridge line in service;65 MW wi/o a gas turbine 114192-06-15 IPTI to CEA |Revision of operating limit for ID-113;limit letter is 60-63 MW from Bradley to Soldotna Page 15 92-06-29 Chugach | governor history table 2 DESCRIPTION PTI indicates severe oscillations on the NOTE letter has DSM plots for the memo to Kenai following islanding;letter requests [Kenai collapse of 6/3/92 AEA SWEC to investigate and make a recommendation as to governor corrections to match PTI predicted response 43)92-07-01 |PTI letter to [Kenai oscillations of 6/3/92 were thought |PTI recommends automatically SWEC to be AGC originated,PTI eliminated AGC jplacing one Bradley in deflector and oscillations were still present;when islanded;shows stable oscillations are thought to be caused by __|response;report included in ID- the use of the on-line gains in the PID 45 controller and such gains provide an unstable response 44/92-07-08 |Chugach Quartz Creek separation of 7/8/92;Kenai letter to went islanded,one Bradley was placed in railbelt deflector &went off on reverse power; utilities SWEC report included in ID-45 49|92-07-09 |PTI letter to [Cooper Lake at 16 MW could not provide Chugach for survival of the Kenai following islanding;avoid AGC action of Bradley in deflector; 58/92-09-15 Internal Incorrect Bradley Lake relay setting Chugach tripped Bradley to deflector at 59.9 memo instead of 59.8 Hz,setting was corrected to 59.8 Page 16 1/10/97 FID:EDA45 governc....-.3ry table instability due to governor controls, recommends placing one unit in deflector when islanded prior to oscillations, recommend new mode by Woodward - feed forward control TE: high on-line gains;deflector mode uses off-line gains;good description of governor history in letter Woodward mod was fo eliminate 56 92-09-22 PTI fax to SWEC Investigated control instability of Bradley when operating islanded;two causes were identified,on-line PID gains & needle integral gain addition function 97 92-09-24 PTI Fax to SWEC PTI could not verify Bradley governor model through all documentation and recommended field tests 63 92-10-08 TCS report to PMC TCS requested SWEC investigate automatic tripping of a Bradley unit to deflector upon overfrequency detection; Chugach disable AGC during transient periods and let the system stabilize following islanding was the over Hz ever done?{s this the reason for the time delay on SCADA AGC? 46 92-10-17 Chugach letter to Bradley O&D Description of Kenai outage on 10/16/92; good description of Bradley control failures going to deflector Page 17 governor history table PSE EIR ONY.SHHDESCRIPTION:a Richa.ES ae Chae Studies and test procedures to show the PTI letter to |result of disabling the needle integral gain Chugach accelerator disabled;SWEC believes this is the primary cause of governor instability during islanded conditions 50/92-11-13 SWEC letter |SWEC provided a good summary of the to TCS reports and studies done to date for Bradley; 48/92-12-00 ISWEC Test report on Deflector &Torque;Time my report is missing page 9; Report lag of deflector control in actual and not -_[sneak circuit corrected in reflected in PTI's model;gain accelerator igovernor;No speed change was disabled during tests,unacceptable signals accepted in condense performance (too slow);AGC pulse could {mode 12/17/92 mod.;two modes trigger during mode transitions;Governor of oscillation noted modified 61)93-05-14 |SWEC letter |Letter transmits ABB's testing procedures to AEA and test results for the commissioning tests of the SVCs 67/93-07-00 ISWEC Hydraulic analysis of penstock,testing of report to needle stroke,recommended to not AEA operate below 1080 feet with only one unit,operation is possible below 1080 but should use 2 units Page 18 1/10/97 governe..._.ory table ee NAME =:|)73?DESCRIPTION)ee SWEC Report states (pg 1)that the instabilities report on were primarily the result of interaction Governor |between AGC and governor,contradicts modification |92 report it references;Report focuses on the "steady state"problems between Bradley and AGC as opposed to the transient in 11/92 69)93-09-22 |ibid 93 governor mod accomplished 3 things, eliminated high PID gains,increased load/unload rates,reduced power swings between needle transitions(pg 2); 70|93-09-22 ibid test 4(speed to deflector)&5(deflector torque test)resulted in oscillations, oscillations appear when both units are in deflector (pg 7);no longer necessary to place in deflector mode for stability,may be required for Hz (pg7) 71/93-09-22 {ibid Figure 4 shows a large power swing when transitioning from needles to deflector and back.Is this a characteristic of the set point? 72)93-09-22 |ibid figures 6&7 show Kenai frequency with 30 &13 MW load rejection.What would happen if BLPP was on min?Trip on reverse power? Page 19 governor history table c DESCRIPTION pg!-1,transition zones;2to4 19.5 MW, 4to2 17 MW,4to6 38 MW,6to4 36 MW; 78/93-09-23 [PTI report Discussion of deflector positioning error Was this error ever corrected? 26May93@17:14 81/93-09-23 |PTIl report jevent 27May93@ 12:18 event switches _|It would appear they have fixed from deflector (6 needle operation)@ 11 {the transition problem. MW to needle control,unit output only drops 2.5 MW,transition to 4 needles in 12:44 test shows only 0.5 MW reduction;13:14 test to 6 needles only 1 MW 79193-09-23 iPTl report |26May93@17:23 oscillations appeared _jlt seems it can't be determined on unit 2 when toggled from deflector what is causing the oscillations; back to 6 needles.PTI recants earlier no discussion which considers conclusions about oscillations as unit2 that Bradley could be oscillating was only Bradley unit operating,PTI against the rest of the system assumes it is related to unit 2 controls 77/93-09-23 |PTl report jEvent 22MAy93@ 14:31 -Event was a PTI gives a good discussion of trip of QC 626 with 13 MW of export, Bradley units were not placed in deflector by SCADA (I believe the Delta Hz was not enough for detection)and began severe oscillations. the event and basically says they don't know what causes the oscillations,but it appears to be in the gov. Page 20 1/10/97 eID:stD isl DATE:ES NAME Sree governo. ag as etDESCRIPTION: sw ry table 75 93-09-23 PTI gov report PTI discusses an event on 26may93 @ 11:58 hours where the two units begin severe oscillations,one unit was tripped but the 2nd stayed on-line and continued severe undamped oscillations with the system.Mode 1.57 -1.45 Hz configuration scenario for this test,units on-line,breaker status etc.PTI states cause was never determined 74 93-09-23 SWEC gov report Plot 25may93@18:51 shows the load acceptance of Bradley following a 5 sec AGC pulse,however the time the pulse was received is not shown.Therefor it is impossible to determine the response of Bradley to AGC. all of the plots included in appendix 1 should be put in the same base if possible 76 93-09-23 PTI report Plot 26may93@13:58 shows damping of Bradley units following synchronization with Anchorage.Good damping exhibited 80 93-09-23 PTI report 27May93@ 11:05 Attempt to recreate oscillations of previous day.Theory of SVC interaction.Tests w&w/o SVC on- line did not produce interactions 88 93-11-00 Unknown The documentation reviewed to date, does not contain any PTI modelling development.Nor does it contain the PTI model of the original gov.developed by Woodward.Where is it? We may just have to copy all of the non-fiscal correspondence between Woodward and SWEC/PTI. Page 21 governor history table AME solos SCRIPTION SWEC letter |Transfer tripping required for a variety of to AEA line outages,including the loss of the Soldotna SVC. 66|94-00-00 |ABB Abstract on the SVCs ability to improve [Did the paper ever get finished? Abstract system stability on the Kenai 82'94-10-18 |O&D HEA reported the governor has been fixed |Is the letter referring to the oil meeting and the needles appear to be operating _|contamination problem or some minutes satisfactorily.This correction was made _jother problem?after HEA wrote a letter to Fuji about the unsatisfactory needle operation 120|94-11-18 |\Woodward |Report from Woodward Field rep on the Field Report |1994 governor work.Work involved mechanical inspection &repair of construction problems.Control logic was not modified 115]95-03-22 [HEA fax to 'Outlines a governor instablity and unit trip SWEC Page 22 1/10/97 governc aeDESCRIPTION. ory table SWEC letter Responding to governor instability Need HEA letter of 3/22/95 to to HEA problem and event which occurred SWEC and system outage and 3/19/95.SWEC makes a proposal for configuration data.Did investigation HEA/Chugach/AEA do an investigation?Is report available? 117/95-04-13 |PMC Discussion of Bradley governor instability; Meeting and recent governor modification Minutes 116/95-05-08 SWEC Fax |SWEC requests data to investigate a If this info was ever produced it to HEA specific event.Good list of data.would be a good event to start with.Would be interesting to see how it responds to the previous unstable events never explained 87/95-08-15 |PTI Report {PTI investigation of 3/19/95 event.Kenai |PTI had to increase slip to 2 Hz "Bradley synchronized to Anchorage at 0.25 Hz to produce oscillations which Lake Hydro jslip.Bradley went unstable.PTl unable jwere damped.Recommended Project to reproduce instability.PTI]concluded -_[external control of Bradley and Analysis.."_|instability was due to synchronization slip eliminate high gains in deflector frequency mode,lower Hz trip for Cooper Lake 8595-11-06 |IPMC HEA has received a report from SWEC __jrequested a copy of the report Meeting after reviewing the governor instability from Stan.Is this same report as minutes problems.PTI report or did SWEC do another report? Page 23 governor history table 1/10/97 Ee DESCRIPTION:5:NOTES”i 84 95-1 1-18 Bradley Approved W.O 333.05 Governor already requested from Stan Lake improvement -What was this and is it Construction jrelevant to our work? list 118/95-11-30 [AML&P ML&P claims that Bradley is being Was this a change or simply a Letter to operated under AGC as opposed toa._-_-s misunderstanding of the speed AEA "speed"mode and it is therefore too slow |mode?Can Bradley now be to utilize SMES;based on PTI report R77-joperated in anything but speed, 95;is this the same report in 1D 87 &85?condense or deflector?Did anyone respond? 86/96-05-16 |O&D AGC Governor Response and Control Meeting Modification by HEA/AML&P minutes Page 24 AGENDA TECHNICAL COORDINATION COMMITTEE GOVERNOR AND STABILITY SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 13,1988 9:00 a.m. Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Purpose of the Subcommittee II.Overview of Proposed Digital Governor A.Arrangment B.Hardware C.Software D.Advantages III.Governor Stability Study Results A.Results to Date B.Information needed from Utilities for further studies IV.Ajournment Attendance: Dave Eberle Oscar Johnson Afzal Khan David Burlingame Bradley Evans Dan Rogers Steven Haagenson John Huber Myles Yerkes John Cooley John Yale GOVERNOR AND STABILITY AND PROTECTIVE RELAYING SUBCOMMITTEES TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES Thursday,April 14,1988 (At the Alaska Power Authority,Anchorage) Alaska Power Authority Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Golden Valley Electric Association Matanuska Electric Association Municipal Light and Power Stone &Webster Engineering I.ADOPTION OF PRIOR MEETING MINUTES The Minutes of the January 13,1988,meeting (attached)were approved and stand as written. II.APPROVAL/MODIFICATION OF AGENDA The Agenda (attached)was approved without change. III.OLD BUSINESS A. 4585R/CG Proposed Scope of Stability Studies The proposed scope of stability studies (attached)was discussed.John Yale distributed copies of the latest stability study (attached),SWEC had completed for Bradley Lake in 1986. The following points and concerns were noted and should beconsideredintheproposedstabilitystudy. e Is transfer tripping required? e The studies should assume no generation is spinning on the Kenai. @ What happens to Bradley Lake if a unit trips in Anchorage? e Is out of step blocking required? e The effect of Tesoro's 3 MW instantaneous load changes on the HEA system should be reviewed. It was also concluded that dynamic and transient stability of the system should be examined to the extent faults influence Bradley Lake. The schedule for performing the studies was then addressed.It was noted that the studies should be done as soon as possible because the results could have a significant effect on the plan for governor and frequency control as well as the SCADA and relaying decisions which must be made in the very near future. It was the consensus of the subcommittee that the best method of accomplishing the studies in a timely manner may be by change order to either SWEC's contract with APA or,SEI's contract with CEA.It was agreed to have both SWEC and SEI prepare brief verbal presentations for accomplishing the work and present then to the subcommittee at its next meeting. Bradley Evans and Afzal Khan will prepare a revised scope of services by April 22 which will be given to SWEC and SEI. IV.NEW BUSINESS A. 4585R/CG Digital Governor 1.Report of trip to Tokyo in February John Yale summarized his observations of the digital governor proposed by Fuji. Fuji had two governors in testing.One was a triple redundant unit for a thermal station in the far east.The other was their prototype hydro governor.The thermal unit had the governor function only.It was tested and ready to ship.The hydro governor incorporated the automatic voltage regulator (AVR)and unit sequence logic.it was still undergoing testing.Fuji was having some problems with the AVR logic. Fuji Provided Digital Governor References John Yale briefed the committee on the effort to obtain North American references for Fuji's digital governor. Fuji has not provided any digital governors outside of Japan. The only hydro digital governor they have produced was the one prototype seen in Tokyo in February.It is due for startup in July. The digital governor uses the Micrex F series Programmable Logic Controller (PLC)manufactured by Fuji.This is a new series produced starting October 1987.The difference between the F series and the previous E series is the ability of withstanding the IEEE Surge Withstand Capability (SWC)tests. SWEC has requested Fuji to provide North American references for the E series The merits and need for a digital electronic governor vs a hydraulic governor were discussed.The consensus was that the stability studies are needed to determine if it is possible to operate Bradley Lake iseochronously,which in turn will determine the need for the digital governor. One-Line Diagram Comments John Yale distributed a sketch showing how the potential future third unit will be connected in the substation ring bus.The committee requested that,if possible,the gas substation should be physically arranged to ease conversion to a breaker and one-half scheme in the future.A requirement will be added to the substation prequalification document for the manufacturers to review and address such an arrangement. VI. VII. (f John Yale distributed responses to the one-line diagram comments received from CEA and GVEA.The comments made by GVEA and the SWEC responses were discussed in part. Clarifications will be made to response 11 and response 12. The committee noted,in response to comment 9,that thermal protection is not applicable at Bradley Lake,but should be provided at Diamond Ridge for protection of the Sterling Highway line. SWEC will redistribute the comments and responses for further review at a later date. NEXT MEETING The next meeting of the Governor and Stability,and Protective Relaying subcommittees will be held May 5,1988,at 9:00 a.m.in conjunction with the SCADA subcommittee meeting.The next full TCC meeting will be May 5,1988 at 1:30 p.m.Both meetings will be held at the APA Anchorage office. ADJOURNMENT The meeting was adjourned at approximately 11:45 a.m. ATTACHMENTS AGENDA MINUTES OF JANUARY 13,1988,MEETING SKETCH -BRADLEY LAKE ARRANGEMENT WITH THREE UNITS RESPONSE TO 3/7/88 COMMENTS BY FRED LEBEAU OF GVEA RESPONSE TO DAVE BURLINGAME OF CHUGACH COMMENTS DATED 3/7/88 RESPONSE TO COMMENTS FROM TOM LOVAS OF CHUGACH ELECTRIC ASSOCIATION DATED MARCH 28,1988 PROPOSED SCOPE OF STABILITY STUDIES TRANSIENT STABILITY STUDY -JANUARY 1986 4585R/CG . - 4- AGENDA TECHNICAL COORDINATION COMMITTEE PROTECTIVE RELAY AND GOVERNOR AND STABILITY SUBCOMMITTEES BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY April 14,1988 9:00 AM Alaska Power Authority 701 East Tudor Road Anchorage,Alaska e I.Adoption of Prior Meeting Minutes II.Approval/Modification of Agenda III.Old Business A.Proposed Scope of Stability Studies Iv.New Business A.Digital Governor 1.Report of Trip to Tokyo in February. 2.Fuji Provided Digital Governor References. B.One-Line Diagram Comments -Review Comments received on One Line Diagrams distributed in February Vv.Adjournment 4362R/210R/LS Attendance: Dave Eberle Oscar Johnson Afzal Khan Don Shira David Burlingame Vance Cordell Bradley Evans Paul Johnson Tom Lovas John Huber Maynard Gross Sam Matthews Tom Small Myles Yerkes John Cooley Ron Krohn John Yale TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES THURSDAY,JANUARY 14,1988 (At the Alaska Power Authority,Anchorage) Alaska Power Authority Alaska Power Authority Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Homer Electric Association Matanuska Electric Association Municipal Light and Power Stone and Webster Engineering Stone and Webster Engineering It. Tlf. IV. VI. Adoption of Prior Meeting Minutes The Minutes of November 10,1987,were accepted and stand as written. Approval/Modification of Agenda The agenda (attached)was approved without change. SCADA Subcommittee Report John Yale summarized the Minutes of the November 10,1987,SCADA Subcommittee Meeting. Governor and Stability Subcommittee Report John Yale summarized the Minutes of the January 13,1988,Governor and Stability Subcommittee Meeting.Copies of the Minutes and attachments (attached)were distributed.Several minor corrections of typographical errors were noted.The Minutes will be revised by John Yale and redistributed. Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation The State Division of Telecommunications (DIVCOM)is communicating directly with HEA on path and real estate needs.Tom Small stated that they are discussing alternate microwave paths but,he is not sure of the status of DIVCOM's efforts. It was requested that Mike Ridge of DIVCOM be invited to attend the afternoon SCADA subcommittee meeting where the communication will be discussed in detail. New Business A.Summary of Stability Study Results John Yale summarized the results of the Governor Stability Studies completed by Fuji to date. The studies reinforce the preference for a programmable digital governor.This will allow the time constants to be changed corresponding to the isolated or connected condition,and load.Additional stability studies will be performed based on expected load conditions provided by the utilities.This issue is a continuing item for the Governor and Stability Subcommittee. The Subcommittee concluded therefore,that system dynamic stability studies should be performed.A scope of the needed studies will be prepared by SWEC and distributed to the TCC members prior to the next meeting. 3912R/191R/CG 1 { Dave Eberle noted that system stability studies are notnecessarilypartoftheBradleyLakeProject,but if they aretobedone,they should be set up to accomodate continualupdatesoftheRailbeltsystemandfuturestudies.It may bepossibletohavetheUniversityofAlaska(U of A)do thestudiesaSacontinuationoftheIntertiestudytheyare presently working on. Dave Burlingame stated that both dynamic and transient studies need to be done.He believes that U of A already has the database and program to do transient studies. The studies will be discussed by the Governor and Stability Subcommittee after the scope of services is prepared. B.Proposed Homer Operations Center John Yale outlined a proposal by HEA that the SCADA master station presently located in the Bradley Lake Powerhouse Control Room,be moved to an operations center in Homer. Tom Small explained that HEA is looking at Bradley Lake fromtheviewpointoftheoverallKenaisystem.Locating the SCADA master terminal in Homer would enable HEA to monitor the project and their transmission system. The arrangement of the SCADA System and the data that will be available to each utility was discussed. Vance Cordell stated that all of the data that CEA gets on its RTU will be available to the other utilities via DECNET. Several concerns were raised regarding the data to be monitored.It was decided to discuss these issues further during the afternoon SCADA subcommittee meeting. Additional Items Discussed. Dave Eberle asked HEA about the status of the contract with Tesoro.Tom Small responded that negotiations were ongoing. Tesoro is starting construction of 4 units,8 MW total.The final outcome will be known mid-February or early March.This information is needed as it will affect the scope of the system studies. Dave Eberle handed out revised project schedules (attached) that were approved by the APA Board in December.The first handout shows a comparison of the Original Schedule,a Revised Schedule created about a year ago,and the current Proposed Schedule to account for the one year APUC delay.The second and third handouts show a breakdown of the new schedule by contract upon the APUC review exemption becoming law by March 15,1988. Tom Small noted that previously HEA's transmission line was required by winter of 1990.He asked if that was still valid. Dave Eberle responded that APA is'planning on HEA's transmission line being available by October 1990,so APA can backfeed power to the Project. 3912R/191R/CG 2 VII. VITI. IX. (( HEA asked approximately how much load would be required for the backfeed.Ron Krohn responded with an estimate of three to five megawatts. Dave Burlingame asked if a Relay Subcommittee existed.He was advised that one does exist.However,it was proposed that the protective relaying be discussed in a combined subcommittee meeting with the Governor and Stability Subcommittee. Next Meeting The next meeting of the Governor and Stability and Protective Relaying Subcommittees will be held on April 14,1988,at 9:00 a.m. at the APA offices in Anchorage. The next meeting of the TCC will be on April 14,1988,at 1:30 p.m. at the APA offices in Anchorage. These dates are tentative and will be confirmed later. Adjournment The meeting was adjourned at approximately 11:00 a.m. Attachments Agenda Minutes of January 13,1988,Governor and Stability Subcommittee Meet ing Bradley Lake Schedule Comparison Propos ed Completion Schedule Bradley Lake Contract Target Dates 3912R/191R/CG 3 VI. Vit. AGENDA TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 14,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska Adoption of Prior Meeting Minutes Approval/Modification of Agenda SCADA Subcommittee Report Governor and Stability Subcommittee Report Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation New Business A.Summary of Stability Study Results B.Proposed Homer Operations Center Adjournment 3603R/CG TECHNICAL CUURDINATLING COMMIS TEE GUVERNOR AND SIABILITY SUBCOMMITTEE BRADLEY LAKE HYDRUELELIRIC PROJELI MINUIES WEDNESDAY,JANUARY 15,1988 (At the Alaska Fower Authority.Anchorage) Attendance: Dave Eberle Alaska Power Authority Oscar Johnson Alaska Fower Authority David Burlingame Chugach Electric Association Bradley Evans Chugach Electric Association Daniel Rogers Chugach Electric Association Myles Yerkes Matanuska Electric Association John Yale Stone and Webster Engineering Ron Krohn Stone and Webster Engineering f I.ir pose of the Subcummittee Mr.Yale distributed the aqenda to open the meeting.the purpose of the subcommittee is to discuss relevant issues regarding the unit governors and their effect on system stabilitv.Aliso,this subcommittee will address relevant issues of system stabiiity in regards to how the project will effect the system and how these effects will be handied.Jhis purpose of this particular meeting is to discuss the features of the governor to be provided by Fuji and familiarize subcommittee members with the hardware currently being proposed.the agenda for this meeting is listed in attachment 1. II.Overview of Proposed Digital Governor. Mr.Yale distributed a Fuji brochure,attachment 2,which describes the Fuji digital governor.He then distrubuted attachment 3.a block diagram of Fuji's digital!governor anda Gescription of Fuji''s philosophy regarding reliability and redundancy. the governor is based on Fuji''s MICREX-F500 Programmable Logic Controller (PLC).it is based on the Multibus II bus.All components are on plug in cards mounted in 19"racks.Ihe governor utilizes triplexed main processor units,and duplexed input/output hardware and busses.Critical inputs/outputs such as unit speed,unit trip command,etc.are also triplexed. ihe arrangement being considered for Bradley Lake will integrate the functions of Automatic Voltage Regulator (AVR),governor,and the umit start/stop logic in the PLC.Fuji 21s currently completing work on their prototype for a similar hydroelectric project utilizing this three function integrated arrangment. Fuji has furnished approximately 70 installations utilizing digital governors in steam and hydroelectric applications. However,they are not fully integrated applications. Mr.Yerkes suggested that Stone and Webster obtain an experience list from Fuji on the application of their digital governor. Amoung the information sought should be a list of digital governors in North America,case history on therr service records,response times by Fuji to service requests,and mean time between failures. Mr.Eberle stated that Fuji would be testing their prototype of their latest digital governor which would be applicable for Bradley Lake.ihis prototype 15 being furnished to a Japanese atility.Mr.Eberle offered to send a representative trom the subcommittee to witness this test if the committee thought there would be any benefit.After further discussion,it was aqreed that this would not be necessary until the factory testing of the actuai Bradley Lake units being furnished. fhe discussions ied into software programing for the PLL.Lt was stated that programing 1S similar to FPLUC''s made by Allen-Bradley { and General Etectric.Concern was raised that the Owner/oper ator entities need to be able to correct software errors without having to depend on Fiji.Wuestions were raised relative to how much traaning would be received trom Fuji.items Such as software,training,and Spare parts will be included in a change order to the comtract to Fuy).. ii.Governor Stability Sudy Results Mr.Evans of Chuqach requested that Stone and Webster supply hain with the assumptions made during the performance of the load ftiovw and stability studies made in late 1985.Mr.Krohn will send it directly to Mr.Evans. lsolated operation of the Bradley units was defined as operating without a gas turbine connected.fhe normal method of this occuring is for the line between Soldotna and University to trip. Since this can occur in a multitude of locations,there may be a need for Chugach to develop a SCADA signal to automatically indicate this condition.It was suggested that in lieu of a SCADA Signal that is dependent on 4 to 10 second scan update times,it might be prudent to detect this change of condition based on the size of the load error signal.This item will be further addressed bythe SCADA subcommittee on January 14,1988.It was also noted that while operating in this isolated,isochronous mode,that the Bradley Lake units cannot control frequency. Mr.Yale distributed a submittal from Fuji on the governing stability,attachment 4.It illustrates the model for the governor and indicates response characteristics based on standard TEEE parameters for load cases specified in the turbine generator contract.Ihe diagrams illustrate the need for a variety of governor settings based on the load condition and on whether or not the unit 15 isolated.fhe easiest way to implement the required variety of governor settings is by use of the digital governor with software change of the settings based on the inputs to the governor. ihe cases studied to date were arbitrarily selected by Stone and Webster based on experience.the utilities need to advise Stone and Webster of their recommended assumptions for toads,toad changes,and acceptable transients tor future governing stability runs.Additional items to be addressed by the utilities are the identification and clarification ot loads to be carried during isolated operation and the point of disconnection to be assumed as this will etfect the load. Mr.Eberle added that the discussions so far had addressed only operation ot a single unit under isolated conditions.He indicated that the chances were that both units would be operating rather than just one.Mr.Yale responded that although that may be correct.the worst case for stability 15 with only one unit operating.Iherefore,1f we can make one unit stable, both units will be stable.two unit stability will be examined aS part of the studies for the non-isolated condition. "YDd4eL)JO Pus BYQ YeEau auTqjauNas AQ {ttm burqQaaw AxaN "CW GIIZIT 3e pPausunofpe sem hurjaay quawsnofpy "AT "Paster suoTtysanb ay.ua juaudrnba tng +0 S4uaumo 4uasaud woiujy asuodsau afrqeuoare}03 ZDAaALQns *tayqeqdaaze aq Prnom souuaaoh je.1r6tp pasodosd ayy 40 asn jeuQ paawhe dnoub ay] "AQTTIQeas ButrusaacH u90o}y SRINSAY APTaANsud OU TTI YT *sOutms 4Aamod puozas pue 4ASut}y SYR AyTUO 4wO}y POOH Sst 3ANq "AQITI|QeAS quatsuesQ 4043 Tapow poot e st weuboud sty eweuhoud AZITIGeSs TH¥4da aTQerrene ATrpeau ayy Hurtsn pawuo;uad aq sun AQITIQes 2&4 Papuswwodxau pue pazruboexau sem QI *sunyu AQITrIqeys saqndwos pastnbau pue sqZ 2npoud pua auryap prnoys pue sarsurburzuos AUPW APNYDUL PTNOYS SaItAsuasg 40 ado dS ay]*4a3SqQam pue auaysS AQ Gasuewsoysad uoOzy ATTuePSSardau You *swuay DraauaH ut aq TItm weshbdaid yons *aSAQTMWwOIGnNS ayy Aq matAayu wos wWeuHoud e YDNS 4oOy SAITAUaS #0 adoxsS e&aoyTaasap OF ATFPA PueSe UYoOUY "Sussay ysanbau sanamoy ptp vay *APNAS auy 404 Paau pue 4S09 *adorms ayQ yNoge auow Ht reoeiu WNOYAIM APNAS YINS OQ Vdy FZIWwWOd AOU HPTNOD aT4ueqg "ap "we 16040 Ppautnbau ayQ YStTaworve Of SAITQETTAN ayy UsanQaq ares uaqurT ay se aAuas PTNOD vay *sQnafoOud snorAaud pue arQuaqUuUT ayy UQIM a rrq3.eud ysed uo paseq Sst sty}"APNAS AQRTITFIQSeAS waAsAs JYeP4aaoUeSxyeR42@PUNPTNOYSYdFEUSaRQtwwaxgqnsayyAqpaysahbnssemAI "SUONTRIPUOD PaQeTOST Outrunp wuorqyesadoa ayy Atwry aq arqe aq Aew JeuR sqQuawaauGe Aue pue *juawdtnba Burqueqgs 40 adAQ *uOgT_Ze4uadO 40 UOTIeUNp pue Aduanbas}|aq TTIM Papaau wo Tew s04UIT "ATRTIDSF OutTrTpuey Teor ayy pue Ayty Gtys ayy Se YANS Puemag je Epeo]abuey uo papasau aq OSTe TTIM vuoTQewsojUT *Qucsaf 2e Sud jOW dH O0GZ &yz se yuons speoy abyvey of aBATIeTaU ATTetzIadSsa *YSH wousy Pautnbasw aq TIM speQyT seTNHaust vO vuoT_QewUOFJUT PeEUOTQ TPpPy *wayqoud AQITIQ@eys ayQ Outrqenrsbe ATQtssod *un 37a 03 buIppays Peay.AtzZewoyNe asned PyNoM suotsunsxe Asuanbau}y asayy}"sawayrs Outppays peor;Arduanbaw.y Moy ayy 3738443 PYTNOM STYQ WeSYR YZnNO pPaRZutod sem QT *abueyo paads wnuwtxew %G sAOF Suan t(IN4 AQ SATPNAS AQITIQFYS AYQ sos PASN eSTABRQTIAD aut *peqzeros:BurQesado yrmafoOuy aye,AaTPe4g ay 4szar0 passaadxa BusamM SuUsNaDVOD se TWwis *paqejost BbBurqeuadgo arttyum AQTPraezs burusersod uo Sqn,ajyse HurQeQeecap pey speay,[Tflews Oursoyts.a.4 €e YINS SUOTIZDIE wWAASAS Syawre Yeyq_Ano pa Rutaod sem At pue yoalaag QAxEQ A043]SYR YUIIM adUaIyadva OAuT paqytyws sug ts|endetp at f ( Vv.Actzons Required Action #15 Stone and Webster to solicite antormation from Fujzx and utility users regarding digital governors suppiied by Fuji. Action Hes: Stone and Vebster to report on Fuji digital governor prototype demonstration in Japan on March 7,1°88. Action #3: Stone and Webster to prepare scope of services for a raialbelt system stabality study.this is to be distributed for review in advance of the next subcommittee meeting. Action #4: Homer Electric Association and City of Seward to provide data realative to irregular major electric loads as discussed relative to isolated operation.Stone and Webster will contact respective parties to clarify the information required. Attachmentss 1.Aqenda 2.Digital Control System for Hydraulic Power Station -Fuji Electric 3.Governor Block Diagram and Reliability Criteria --Fuji Electric 4.Governor Stability Model and Simulation Results -Fuji Electric qa AGENDA TECHNICAL COORDINATION COMMITTEE GOVERNOR AND STABILITY SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 13,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Purpose of the Subcommittee II.Overview of Proposed Digital Governor A.Arrangement B.Hardware C.Software D.Advantages III.Governor Stability Study Results A.Results to Date B.Information needed from Utilities for further studies IV.Adjournment 3603R/CG uli SUecrtelG Digital Control System for Hydraulic Power Station SortONGai New Technologies for Hydraulic Power Plant Applications Recently,a programmabie controller (PC),a digital control device incorporating a micro-processor,has been put in practical use for broad applications,rather than using con- ventional electro-magnetic type control devices,in order to provide higher reliability and simple maintenance of hydraulic power plant systems. The programmable controller is capable of high speed transmission of large arnounts of data through a dataway as well as multi-function processing and high speed conputation due to the rapid technical progress in the field of PC's coupled with developments of new peripheral devices such as a CRT display. The MICREX-F500 having such features is designed as a total digital system for hydraulic power plant systems;and is being _used not only in conventional control but also for hydraulic turbine governors (hereinafter called governor”),automatic voltage regulators (hereinafter called AVR). This programmable controller is highly efficient,economical and reliable. Advantages of MICREX-F500 (1)Adoption of unit type hardware and software for added functions has resulted in a compact device embodying enhanced cost-performance. (2)1/0 units can be instalied in various places where data are concentrated so that data can be collected by using a simple cable route. (3)The MICREX-F500 can be used not only for a newly installed hydraulic power plants,it can also be used for replacement of existing control systems in such plants. In addition,it can be used in combination with a sequence controller,exciting device or governor. (4)With incorporation of an operation panel,full scale man-machine interface functions can be accomplished. (5)Use of intelligent Al cards eliminates the necessity of transducers for external analog input/output interface. Functions of Digital Controller for Hydraulic Power Plant Tabie 1 shows the major functions of the digital controller. Fig.2 shows the functions of the digital AVR,and Table 3 shows the functions of the digital governor. Table 1 Functions of Digital Controller Funetion Typical example (1)Sequencing (a)Startup and stopfunction(b)Emergency shutdowne1)(c}Normal shutdown (d)Au i¢switchingofhouse p(e)Automatic reclosing (ft)Aux,machine control (a}Automatic voitage regulator contro! (b)Governor speed control (c)6SF,65P control «Automatic power control «Automatic frequency contro! (4)SOR control «Automatic VAR controt «Automatic power factor control (e)77 control °Automatic headwater level control *Automatic flow rate control (f)}High efficiency control2)(g)Various program operation (h)Joint operation {a}Incomplete start/stop sequence (b)Main machine status conditions (c)}Aux,machine status conditions supply system (2)Control function (3)Sequence monitoring function (4)Remote (a)Control signal receivingterminal(>)Numerical setting velue receivingunitle}Supervision signsi transmissionfunction(d)Measuring signa!transmission Remarks °1)Used together with magnetic relay emergency shutdown circuit. °2)Impulse turdine,Kaplan turbine Fig.1 Total Digital Control System Block DiagramSeceemammecommeeeamecmeee©a ey rNP1beetsaane Table 2 Functions of Digital AVR eoTable 3 Functions of Digital Governor Function Contents Function Contents Cross current compensation Prevention of VAR current from flowing into each units when 2 or more generators are in parallel operation Field current limiting Generator field current limit in drushiess exciting system Characteristics Ocead band:0.02%01) Oeat time:Less than 0.25 sec o1) Range of adjustments Speed:90 to 108% Permanent speed droop:0 te 10% Momentary speed droop:0 to 50% Time constant of damping:0 to 15 secMinorcontroltoopwithTimeconstantcompensationin a feedback signal of the brushiess exciting system _Basic calculation P10 operation (with 65F and 65P functions) field current Wicket gate opening Wicket gate constant opening operstion(77)Frequency compensation Synchronizing signal compensation control : against speed rise at load rejection Water level control Upper reservoir constant water level Smooth voitage build-up Voltage overshoot control st selection operationfromfieldflashingtoAVRoperationOutputcontrolAPC,AFCReactivepower|Leading Prevention of stator core local overheat Power output Load distribution operation during paralieirestrictionLaggingPreventionofrotorcoiloverheatstablecontroloperationof2ormoreturbines Generator AC current Prevention of stator coil overheat High efficiency Optimum runner vene opening (Kapanrestrictioncontrolturbine,Bulb turbine} Frequency drop Over-exertation compensation (high s 1g the §ber of dies used compensation voltage sync.only)of main trans-(impulse turbine) former in tow frequency Automatic soeed Function of automatic synchronizing Automatic reactive power APfR,AQR (Q=sa+bp).regulating device (#15) or power factor regulation Automatic fottowup Faltow-up to 65F to 77 during water Line charge Line charge controt regulating operation (77) PSs SP detection sytem Over power restriction Restriction of over-power Manual voitage regulation ACR system (Detection:Fieid current)Soeed droop operation Computing speed drop Automatic follow-up Automatic followup of manual signal Speed relay 13,14,141 02) control Remarks °1)including mechanical control unit Automatic voltage bslancing Function of automatic synchronizing °2)12 is instalied separately device (#60) were te -0 ome eS NMR Ee a eRemeeeecee 5 Olea AVA i-*Effec wves/rear weenw |a.fit]ttywenster.conwre manen-$$-_-_--om Lameeng!+Over esqiteuentermedung formrteng bene +Inga mMereterngroreng+Cust mermienng ee a eee a Fig 3 Digital Govenor Block Diagram -ee ee we ee wee em 228 2G Ouvwec-§*Frenuancy (SSG)lo mm o wr *Waret ge comwung+Etternweeer Ceara |>Sreaventy connorWatewnen+Wacol qete enarung§tC enteate }canwes eumcwer -»Seuss areneacometenen 3 +Seeve conwas tower erwen Dave wna ||>+EteceeesumerootoremsrePiorte)sore srvemnewr cenvervey 3 Lewteng|*Werner gues ceengweestomeTurmeneeverqueLeamdaetnJ Mane tongs)Premmeteseytoreng+Cutest morterang+fant Geegrees °Fuji Electric Co.Ltd. 12-1 Yurakucho 1-chome.Chiyoda-ku.Tokyo.100 Japan Phone Tokyo 211-7111TelexJ22331FUJIELEA or FUJIELEB 2-2 High Reliability Design (1) (2) Basic Concept Two basic approaches for the improvement of the reliability of control equipment are as follows.- 1)To build up the faultless system (prevention of failure). 2)To prevent the effect of failure to the whole system (minimizing the effect of failure). And our concepts of the redundancy are mentioned below. 1)A system which is capable of self-diagnosis should be duplexed. 2)A system which is difficult of self-diagnosis should be triplexed. 3)A system which is difficult to be multiplex should be not concentratec D-EHG system configuration The D-EHG system is built with the following configuration: 1)Main Processing Unit (MPU):(Fig 2-1-1) Be triplexed,because it is the most important part of the systen, and the self-diagnosis for computed results is impossible.. 2)Control power source supply:(Fig 2-1-1) Be duplexed to assure the control system,even if one of the lines is down. 3)Input/output unit:(Fig 2-1-1) I/0 unit is duplexed commonly to 3MPUs,because self-diagnosis is possible. AO_(HRAO)(Fig 2-2-1,Fig 2-2-2,Fig 2-2-3)® AO is duplexed (or "OR connection)because af ranshiers..-F khen a failure is detected in the 40 card,it is turned off and Simultaneously the another AO card oa standby is on. D0 (Fig 2-2-4)Ko) Same as AQ.. DI (Fig 2-2-5)|© Same as AO, But some important i/os mentioned below are triplexed and directly connected to MPUs. Triplexed PI +Input of turbine rotation detection (Fig 2-2-6)® Triplexed DI_(Fig 2-2-7) >Input of 526 -Input of turbine trip -Input of PT fuse blow -Input of turbine starting system Triplexed DO (Fig 2-2-8)|® *Output of turbine starting system Triplexed AI -Input of control valve opening detection (Fig 2-2-9)|®-Input of generator output detection (Fig 2-2-10) -Input of WT ITM (Interface Terminal Module):(Fig 2-1-1,Fig 2-1-2)|@) Be simplex for each i/o signal,because of duplexed I/0. Input/output serial link (T-link):(Fig 2-1-1) Be triplexed because the MPU is triplexed. MPU serial link (P-link):(Fig 2-1-1) Be duplexed. oaneeeaePou lees m=}estestestestcetestTa PROGRAMMING mura Ssreur 100L mA al A a 1 ann JN ¢outa >mm Sots GOS OT mrrerereeseo_o ToL INK net oc-8 I/o-t SELF rr..._Wont SELF Tus 1s 1s POW Ls ms ws i ° eATE Ouse oalt bute bia ¢<ome}eo)|PGA Gee |wae iFan)Fn +MaO]{YRAO}|OF Oe Oo HRADT [HRAOT [PMA][HRAOT |OF 01 Ove Oc (fon Jin OF 01.000 rs |](Td a der a ver ' 2 De }fus i|(7)'|il von]oe ve]fur {es}for il Oe ]{u.i]1]QUICA POMC BPAY foe 170 {rs RYot)TU i}{i TOTTI)"wea ie v r 'e Ul eam |IE Tinea scr POA BAT FOR PtLar ty L +-es t aa °uvcPteceawfLPSoeYd --dt -J.e/Fb -J-l--J--FRK4t4+------=1 ico wnirun cd PS (belt ed owe] [tots swan unend mate fete WwPOwARE nAeCENT ALAA)'\,bbe |ee,ersten vecent msn +.7 ®1@s COLCH POTR BLPPLE UROE nS AL aancia?|AP,CCG POOR BPPLE rAectnt annL 2 TAYJAN.10,0907 POWER SOUNCES NIE REVISED.==DATE NAME cul Electde €r O-EHG CAROS i Fig 2-t-01 anuecineUc Dec.15.07 ofarp "=]ANDO POWER SOURCE CONSTRUCTION [> )Revised 19,'87 a & 1.Outline The stability of turbine governor for Alaska Power Authority,Bradley Lake Hydroelectric Project was analyzed using a simulator.(SHYTAP) As the result,the setting of governor constant in Table l was determined appropriate,as follows. Table 1_Governor,Constant Constant Name i i £j|,,......Set value. Power Output203%70%90% Proportional gain Kp 1.8 0.7 -0.9 Integral time constant Ti 10.0 20.0 20.0 Differential time constant ,Td 1.1 1.1 1.1 Droop bp 0.03 2.Condition for Calculation 2.1 Governor function is shown in Fig.1,block diagram. 0696S Ld65Pa DEFLECTOR /NEEDLE CURVE +1 OEFLECTORris100Isos_ 77E 4 Ts9=2,0 Kp Sof +.100 i NEEDLE NOI +-01 -t Tsn 2600 "=¢0*}38 :_NEEDLE NO2 NO6 rereyz Cc +003 =e-NEEDLE NQ2 NOS CALCULATION OF TOTAL "OPENING FOR NEEDLE FIG1,BLOCKDIAGRAM FOR GOVERNOR l- S.W.E.C. i BRADLEY LAKE P/S CASE R-4-2 aWVTes AD cS 3 Vv&=< >8 23 StS hi& q="lwwe Sus ™ sy=-ley - = Ss=ht z= AnSsPave a :;iropa Po a of (=, Pr: ff = -- :ii|oo o¢ >oa ::!on]4 4 -" :t;3 2 H wo al Fs. riot Eo > sob gt =e tot r= 4 ' xno :: ' EOPtTBye5i aN a3 . m 5i! aoeboiiSi:itg [eeiii+aDorf x= fs4 =iS :: ' -<rce pif Bxe PPPB BOS ai noc "3' ao itoj mou 7 udiSitg{f,VL PRIOR e sw.ON ; 'i ': SoS :wens:' re : N see! LS : ™N rae | $=;: SSS see eneot ' - : Qo on r= 38 oD : ARES w wenn nen , Se Neem eeeenea So (4) ON : (41 38888®88¢&&8S©§[FEE(W} THe 2832=5: - r - = + - laa = = = mH 108 3Ss e2&® 8 8282 ¢?88S €§ it: (41 INSR° 83&e33.°*°] 7t1 a oe rey 2.Fa}. teeetcaeaNtonee|wetNwehwes!etad)4)(Z%)(%=SN1SOT&860 |60 60 UM)70}70 70 60]60 [360]60 rq 526% SO}SO }370 |SO |reeTREETSTSS 404 40360;40 30 |30 [450 {30 20]20 1340]20 107 10330]10 0 50 100 150 200 250 300 380 400 450 500 S50 61)650LIME(Sec) ------POC PCE=59850 KH CO2=exee THM ceeeeevooseoe AE He =358.32 H QO =2t.87 N3/S --------Of N =300.0 RPM Ataska Power Authority BRADLEY LAKE SCHEDULE COMPARISON 1987 1988 1989 1890 1091i|||i J i 1 |I J T T T ORIGINAL SCHEDULE UNIT 1 00c e108 NTP RESERVIOR TUNNEL oO” art @/t)7796 ert VO/1 929 279 -4 KG.A A LLAMA AAA 1 uo l. |mae bastacl REVISED SCHEDULE (3/13/87) 19SueE OPEN FILL FILLE «UNIT 1)UNIT 2 DOC BIOS NIP AESEAVIOR TUNNEL Om OM 6/18 7/18 Of 10/1 ai v/a)«(Ost t-T k SSSAWI|31 Mo T moee ee PROPOSED SCHEDULE ISSUE CALL von81DFOROPENFILLFILL UNIT 2 poc BIDS BIDS NIP RESERVIOR TUNNEL \one/a 3/16 6/96 TI my an Th)es-_--_-JY.bootie:iH ' | |a $2 Mo sf?| |J |||l !||||l |J | 12/67 Bradley Lake Hydroelectric Project PROPOSED COMPLETION SCHEDULE 19868 1989 19980 1001 leeve Cid Notice to Proceed FMRBidDocOpening(NTP)(tt Reservols Fill Tunnel CompCONSTRUCTIONeres?6/18 781 TAL |ast ert i -'Y bd 4 GENERAL CIVIL iz w/Bia q NTP 3/16 6716 6716 CAMP &CATERING cee,1] tnoteill Start NTP Embedded Parts Testing en o/1 10/18 7116 ba =- d ¥bd POWERHOUSE Gia Construction 1 NTP 3718 6/1 O71 bel |T/L CLEARING Bid J NTP 6st Pee ert to | T/L CONSTRUCTION ales Procurement |[..Gonetruction } wre 12716 3/0 401+7 *-c>T{[7NUKA/MIDOLE FORK DIVERSIONS Ployy "Te ast ont test ¥Ld y rySITEREHABILITATIONShipae| Embedded Ship ai wre Paris Turbine/Generator 3/16 3/16 0/16PROCUREMENT_¥bd d ' )Fabsicete tnetatt and Tease TURBINE /GENERATOR -ba { anu @706 ris Py install and Test BCADA ia ,-||| taser i]AY £=>Alaska Power Authority Pe 2 &2 &2£Ss ABRADLEYLAKE”fe?é Pd5)S v 3 Q 3CONTRACTTARGE%a 2»6 S .GET DATES $d o¢e eo q) GENERAL CIVit 9/0/87 |6/16/88)7/1/88 |N/A |379701 |O7ss01 t CAMP &CATERING 3/16/68 |6/16/88 |6/16/68]N/A N/A 0/1/01 3/16/8TURBINEGENERATORN/A NIA |avt6s08 |e eee giro |ovtzo49/16/80 SCADA 4lt;as |6/16/68]7/16/88 |1980 |1/1/01 |971701 POWERHOUSE 6/1/08 |9/1788 |10/16/88|NVA 1/1/01]o7ss01 T/L CLEARING 3/18/88 |6/1/88 |6/1/88 N/A NA 1/1/80 T/L CONSTRUCTION 6/1/88 |7/1/88 |O/1/e8 |1080 N/A |0/1700 NUKA/MID FORK DIVERSION |10,16;89]3/1/00 |4/1/00 NIA Nsa_|10/4/90 CONSTRUCTION SITE REHABILITATION 2/1/01 |astso4 |671701 NIA NIA |aasesat 19/67 RAG)|CASE 20027 "4 ee!4 aei ee ed ee _:=-hh CASE.10022 ras5 Ps :._%\a NINA NON .a Rie ete reeronere se:ernmmementswees 88 Lew pe Se ene ss STRESS SUIS TMS TST ECTS at 3a 5 TV st ss awe --=S cee CASE 20023 -4]----|----|---A -TT NN ne a re --|Kee}-So ="= ee |b_eeee _"A,7 - ee ee -a |ee \o a seeeet ey -_-se ome se ee --_---we:-am 4 N wees we .eee 2 ts res decemevan ome qainss seme ||ESET eerie ean ce ---Dee °"-*-_-aha @ es a ..s -* ou ZL 0 Tas d§.0.UL TTT on Dore Nore 40/0 LOAOFujiElectricCo,Ltdfi Fiz3-TTnLaet.T oO °|Oe _-So CASE Aol 2] «6 5&8 @ &6 wee Ss ACASE Jor Ja a er a a ee ear ---nl |of ae -Ly ule]a fCAS@ 20222 - - et 0 A a se 2 CASE 20423 ET|sooo NJ oc To < A rEOL Pe i oe, cmM-02-0|CASE Fol 2)oo ae ee cece ae (eee ™N SS N . N N NS. __\eo @ 8°a2 6G 8 8 8 #Kookeeet ee ee i i nd (CASE 70092 Caaee|oa|CASE 90 032 Cr ee ee ee ee eeeee et ee ee ee ee ee ee ee BOP TOcasemona ---- =- \--ifnoSSSSE |kp |NO a TT ee -: a sooo ON :7 <cor pres bome Te +of <4 aid Peel ee mo Ng es TH or 5g DS On 2.00 OT enue.130 Fujl Electric Co,Ltd |2 70 Yo LOAD Fay S o 9°'OE .T F CM=-02-0" is CASE 2OTI 2 gt eae oe ete iene OEE ene oe Ow at meeenelfres is*ss[AITer et ee ee ee ee ee ee ee et ee ee eet -]----wfeal fel o cAse Tol a2 ee ee ad eee oe -eam -Th |2}-|----ea 447 -L-.,|Se =TT ht \stuns -k. -t-h eee ee ener!seoseremeseneceeenmer,oa -_-, eee "\M stele| 4 rd A CASE 70 Ij. | ae iLa a ss 6 LE ee ae (CASE Fol 23 aSeeeSeeee See eer ee et ee ee ee ee 10__0 a Fujl Electric Co,Ltd.|2 70%LOAD .CASE90O27F |ease coo ta Se X 1 ''\2 ALLLTTT|peeneel '3 -oa.,tO gett teen eeeettttteeammenemnconmame62+ a ow apa]a 4 a 4 -.es eee an none ; ee et,ee eee zs tt 8 8 8 6 8 ©ads cS 8S 5 5 SS 8 Se ae on N ' |}"7 iN ' wm NN Be _-oS 8 s_8_as Ba Ba Oe - of [om eas TW (520 --- owt__t_tere 0%LOoAO f 2FujlElectricCotala|7°”i WAOreen Checked: a fip 7oOO1E a|CASE fotas aS ss" >mene ss Se mepete |S\aee |:Case fot da :Case lo -ea|” ene 132 ese, ss 6 s ©©&S&S S&@ &=*LT _Sener eee _----.reer ==7 -|case_Qor23__"oo -yKtrt eg NT:oe se |EF 100 (A Fuji Electric Co,Ltd |?Govo LOAD --Fig§4 fjMT)toeetta”wal Attendance: Dave Eberle Oscar Johnson Afzal Khan Don Shira David Burlingame Vance Cordell Bradley Evans Paul Johnson Tom Lovas John Huber Maynard Gross Sam Matthews Tom Small Myles Yerkes John Cooley Ron Krohn John Yale -_-:ATTACHMENT 3 TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES THURSDAY,JANUARY 14,1988 (At the Alaska Power Authority,Anchorage) Alaska Power Authority Alaska Power Authority Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Homer Electric Association Matanuska Electric Association Municipal Light and Power Stone and Webster Engineering Stone and Webster Engineering II. IIl. Iv. VI. Adoption of Prior Meeting Minutes The Minutes of November 10,1987,were accepted and stand as written. Approval /Modification of Agenda The agenda (attached)was approved without change. SCADA Subcommittee Report John Yale summarized the Minutes of the November 10,1987,SCADA Subcommittee Meeting. Governor and Stability Subcommittee Report John Yale summarized the Minutes of the January 13,1988,Governor and Stability Subcommittee Meeting.Copies of the Minutes and attachments (attached)were distributed.Several minor corrections of typographical errors were noted.The Minutes will be revised by John Yale and redistributed. Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation The State Division of Telecommunications (DIVCOM)is communicating directly with HEA on path and real estate needs.Tom Small stated that they are discussing alternate microwave paths but,he is not sure of the status of DIVCOM's efforts. It was requested that Mike Ridge of DIVCOM be invited to attend the afternoon SCADA subcommittee meeting where the communication will be discussed in detail. New Business A.Summary of Stability Study Results John Yale summarized the results of the Governor Stability Studies completed by Fuji to date. The studies reinforce the preference for a programmable digital governor.This will allow the time constants to be changed corresponding to the isolated or connected condition,and load.Additional stability studies will be performed based on expected load conditions provided by the utilities.This issue igs a continuing item for the Governor and Stability Subcommittee. The Subcommittee concluded therefore,that system dynamic stability studies should be performed.A scope of the neededstudieswillbepreparedbySWECanddistributedtotheTCC members prior to the next meeting. 3912R/191R/CG 1 Dave Eberle noted that system stability studies are not necessarily part of the Bradley Lake Project,but if they aretobedone,they should be set up to accomodate continual updates of the Railbelt system and future studies.It may bepossibletohavetheUniversityofAlaska(U of A)do thestudiesasacontinuationoftheIntertiestudytheyare presently working on. Dave Burlingame stated that both dynamic and transient studies need to be done.He believes that U of A already has the database and program to do transient studies. The studies will be discussed by the Governor and Stability Subcommittee after the scope of services is prepared. B.Proposed Homer Operations Center John Yale outlined a proposal by HEA that the SCADA master station presently located in the Bradley Lake Powerhouse Control Room,be moved to an operations center in Homer. Tom Small explained that HEA is looking at Bradley Lake from the viewpoint of the overall Kenai system.Locating the SCADA master terminal in Homer would enable HEA to monitor the project and their transmission system. The arrangement of the SCADA System and the data that will be available to each utility was discussed. Vance Cordell stated that all of the data that CEA gets on its RTU will be available to the other utilities via DECNET. Several concerns were raised regarding the data to be monitored.It was decided to discuss these issues further during the afternoon SCADA subcommittee meeting. Additional Items Discussed. Dave Eberle asked HEA about the status of the contract with Tesoro.Tom Small responded that negotiations were ongoing. Tesoro is starting construction of 4 units,8 MW total.The final outcome will be known mid-February or early March.This information is needed as it will affect the scope of the system studies. Dave Eberle handed out revised project schedules (attached) that were approved by the APA Board in December.The first handout shows a comparison of the Original Schedule,a Revised Schedule created about a year ago,and the current Proposed Schedule to account for the one year APUC delay.The second and third handouts show a breakdown of the new schedule by contract upon the APUC review exemption becoming law by March 15,1988. Tom Small noted that previously HEA's transmission line was required by winter of 1990.He asked if that was still valid. Dave Eberle responded that APA is planning on H4HEA's transmission line being available by October 1990,so APA can backfeed power to the Project.3912R/191R/CG 2 VII. VIIt. ' t HEA asked approximately how much load would be required for the backfeed.Ron Krohn responded with an estimate of three to five megawatts. Dave Burlingame asked if a Relay Subcommittee existed.He was advised that one does exist.However,it was proposed that the protective relaying be discussed in a combined subcommittee meeting with the Governor and Stability Subcommittee. Next Meeting The next meeting of the Governor and Stability and Protective Relayi at the ng Subcommittees will be held on April 14,1988,at 9:00 a.m. APA offices in Anchorage. The next meeting of the TCC will be on April 14,1988,at 1:30 p.m. at the APA offices in Anchorage. These dates are tentative and will be confirmed later. Adjournment The meeting was adjourned at approximately 11:00 a.m. Attachments Agenda Minutes of January 13,1988,Governor and Stability Subcommittee Meet ing Bradley Lake Schedule Comparison Propos ed Completion Schedule Bradley Lake Contract Target Dates 3912R/191R/CG 3 AGENDA TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 14,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Adoption of Prior Meeting Minutes II.Approval/Modification of Agenda III.SCADA Subcommittee Report IV.Governor and Stability Subcommittee Report V.Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation VI.New Business A.Summary of Stability Study Results B.Proposed Homer Operations Center VII.Adjournment 3603R/CG TECHNICAL COORDINAFING COMMITTEE GOVERNOR AND SIABILITY SUBCOMMITTEE BRADLEY LAKE HYDRUELECTRIC PROJECI MINUIES WEDNESDAY.JANUARY 13,1988 (At the Alaska Fower Authority.Anchorage) Attendance: Dave Eberle Alaska Power Authority Oscar Johnson Alaska Fower Authority David Burlingame Chugach Electric Association Bradley Evans Chugach Electric Association Daniel Rogers Chugach Electric Association Myles Yerkes Matanuska Electric Association John Yale Stone and Webster Engineering Ron Krohn Stone and Webster Engineering I.Purpose of the Subcommittee Mr.Yale distributed the aqenda to open the meeting.ihe purpose of the subcommittee is to discuss relevant issues regarding the unit governors and their effect on system stability.Also,this subcommittee will address relevant issues of system stability in regards to how the project will effect the system and how these effects will be handied.Jhis purpose of this particular meeting 1s to discuss the features of the governor to be provided by Fuji and familiarize subcommittee members with the hardware currently being proposed.the agenda for this meeting is listed in attachment 1. II.Overview of Proposed Digital Governor. Mr.Yale distributed a Fuji brochure,attachment 2.which describes the Fuji digital governor.He then distrubuted attachment 3,a block diagram of Fuji's digital governor and a Gescription of Fuji's philosophy regarding reliability and redundancy. the governor is based on Fuji's MICREX-F500 Programable Logic Controller (PLL).it is based on the Multibus II bus.All components are on plug in cards mounted in 19"racks.jhe governor utilizes triplexed main processor units,and duplexed input/output hardware and busses.Critical inputs/outputs such as unit speed,unit trip command,etc.are also triplexed. Ihe arrangement being consideredfor Bradley Lake will integrate the functions of Automatic Voltage Regulator (AVR),governor,and the unit start/stop logic in the PLC.Fuji 18S currently completing work on their prototype for a similar hydroelectric project utilizing this three function integrated arrangmaent. Fuji has furnished approximately 70 installations utilizing digital governors in steam and hydroelectric applications. However,they are not fully integrated applications. Mr.Yerkes suggested that Stone and Webster obtain an experience list from Fuji on the application of their digital governor. Amoung the information sought should be a list of digital governors an North America,case history on their service records,response times by Fuji to service requests,and mean time between failures. Mr.Eberle stated that Fuji would be testing their prototype of their latest digital governor which would be applicable for Bradley Lake.Ihis prototype :s5 being furnished to a Japanese utility.Mr.Eberle offered to send a representative from the subcommittee to witness this test if the committee thought there would be any benefit.After further discussion,it was aqreed that this would not be necessary until the factory testing of the actual Bradley Lake units being furnished. fhe discussions led into software programing for the PLC.Lt was stated that programing 1S similar to PLC's made by Allen-Bradley and General Electric.Concern was raised that the Owner/oper ator entities need to be able to correct software errors without having to depend on Fuji.Questions were raised relative to how much training would be received trom Fuji.Items such as software,training,and spare parts will be included in a change urder to the contract to Fuji. Tal.Governor Stability Sudy Results Mr.Evans of Chugach requested that Stone and Webster supply hii with the assumptions made during the performance of the load flow and stability studies made in late 1985.Mr.Krohn will send it directly to Mr.Evans. isolated operation af the Bradley units was defined as operating without a gas turbine connected.She normal method of this occuring 1s for the line between Soldotna and University to trip. Since this can occur in a multitude of locations.there may be a need for Chugach to develop a SCADA signal to automatically indicate this condition.it was suggested that in lieu of a SCADA Signal that is dependent on 4 to 10 second scan update times,it might be prudent to detect this change of condition based on the size of the load error signal.thas item will be further addressed bythe SCADA subcommittee on January 14,1988.It was also noted that while operating in this isolated,isochronous mode,that the Bradley Lake units cannot control frequency. Mr.Yale distributed a submittal from Fuji on the qoverning stabilxzrty,attachment 4.It illustrates the model for the governor and andicates response characteristics based on standard TEEE parameters for load cases specified in the turbine generator contract.the diagrams illustrate the need for a variety of governor settings based on the load condition and on whether or not the unit 1s isolated.{he easiest way to implement the required variety of governor settings is by use of the digital governor with software change of the settings based on the inputs to the governor. ihe cases studied to date were arbitrarily selected by Stone and Webster based on experience.the utilities need to advise Stone and Webster of their recommended assumptions for loads,toad changes,and acceptable transients for future governing stability runs.Additional items to be addressed by the utilities are the identification and clarification ot loads to be carried during 1solated operation and the point of disconnection to be assumed as this will effect the load. Mr.Eberle added that the discussions so far had addressed only operation ot a single unit under isolated conditions.He indicated that the chances were that both units would be operating rather than just one.Mr.Yale responded that although that may be correct.the worst case for stability is with only one unit operating.Iherefore,1 we can make one unit stable, both units will be stable.Iwo unit stability will be examined aS pert otf the studies for the non isolated condition. the discussions shifted into experience with the lerror Lake Project and it was pointed out that simple system actions such as reclosing small loads had devastating effects on governing stability while operating isolated.Similar concerns were expressed over the Bradley lake Project operating isolated.Ihe criteria used for the stability studies by Fuji were for 5% maximum speed change.It was pointed out that this would eftect the low frequency toad shedding scheme.these frequency excursions would cause automatic load shedding to occur,possibly agrivating the stability problem. Additional information on irregular loads will be required from HEA.especially relative to large loads such as the 2500 HPF motors at lesoro.Information will also be needed on laraqe loads at Seward such as the ship lift and the coal handling faciltiyv. Information needed will be frequency and duration of operation, type of starting equipment,and any agreements that inay be abie to Limit the operation during isolated conditions. lt was suggested by the Subcommittee that APA should undertake an overall system stability study.this is based on past practice with the intertie and previous projects.APA could serve as the interface between the utilities to accomplish the required program.Mr.Eberle could not commit APA to such study without knowing more about the scope,cost and need for the study.APA did however request Messrs.Krohn and Yale to develop a Scope of Services for such a program for review by the subcommittee.Such program will be in generic terms,not necessarily for performance by Stone and Webster.the Scope of Services should include many contingincies and should define end products and required computer stability runs.It was recognized and recommended that Stability runs be performed using the readily available EPRI stability program.fhis program is a good model for transient stability,but is good for only the first and second power swings.lt will not provide results for governing stability. the group agreed that use of the proposed digital governor would be acceptable,subject to favorable response from present owners of Fuji equipment on the questions raised. IV.Ad jourment Meeting was adjourned at 11:15 A.M.Next meeting will be sometime near the end of March. Ve Actions Required Action #1: Stone and Webster to solicite information from Fuji and utzrlity users regarding digital governors suppi1ed by Fuji. Action #2: Stone and Webster to report on Fuji digital governor prototype demonstration in Japan on March 7,1988. Action #3: Stone and Webster to prepare scope of services for a railtbelt system stability study.fhis is to be distributed for review in advance of the next subcommittee meetina. Action #43 Homer Electric Association and City of Seward to provide data realative to irregular major electric loads as discussed relative to isolated operation.Stone and Webster will contact respective parties to clarify the information required. Attachments: 1.Aqenda Ze Digital Control System for Hydraulic Power Station -Fuji Electric 3.Governor Block Diagram and Reliability Criteria -Fuji Flectric 4.Governor Stability Model and Simulation Results -Fuji Electric an I. It. Tit. Iv. AGENDA TECHNICAL COORDINATION COMMITTEE GOVERNOR AND STABILITY SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 13,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska Purpose of the Subcommittee Overview of Proposed Digital Governor A.Arrangement B.Hardware C.Software D.Advantages Governor Stability Study Results A.Results to Date B.Information needed from Utilities for further studies Adjournment 3603R/CG FulBULEGrielG Digital Control System for ydraulic Power Station New Technologies for Hydraulic Power Plant Applications Recently,a programmabie controller (PC),a digital control device incorporating a micro-processor,has been put in practical use for broad applications,rather than using con- ventional electro-magnetic type control devices,in order to provide higher reliability and simple maintenance of hydrauiic power pliant systems. The programmable controller is capable of high speed transmission of large amounts of data through a dataway as well as multi-function processing and high speed conputation due to the rapid technical progress in the field of PC's coupled with developments of new peripheral devices such as a CRT display. The MICREX-F500 having such features is designed as a total! digital system for hydraulic power plant systems;and is being used not only in conventional control but also for hydraulic turbine governors (hereinafter called "'governor''),automatic voltage regulators (hereinafter calied AVR). This programmabie controller is highly efficient,economical and reliable. Advantages of MICREX-F500 {1}Adoption of unit type hardware and software for added functions has resulted in a compact device embodying enhanced cost-performance. (2)1/0 units can be installed in various places where data are concentrated so that data can be collected by using asimple cable route.. (3)The MICREX-F500 can be used not only for a newly installed hydraulic power plants,it can also be used for replacement of existing control systems in such plants. In addition,it can be used in combination with a sequence controller,exciting device or governor. (4)With incorporation of an operation panel,full scale man-machine interfece functions can be accomplished. (5)Use of intelligent Al cards eliminates the necessity of transducers for external analog input/output interface. Functions of Digital Controller for Hydraulic Power Plant Table 1 shows the major functions of the digital controller. Fig.2 shows the functions of the digital AVR,and Table 3 shows the functions of the digital governor. Table 1 Functions of Digital Controller Function Typical exampie (1)Sequencing (a)Surtup and stopfunction(b)Emergency shutdowne 1) (e)Normal shutdown (ad)Automatic switching of house power supply system {e)Automatic rectosing (f)Aux.machine control (a)Autornstic voltage reguiator contro! (bv)Governor speed comtro! le)6SF,6SP control +Automatic power control «Automatic frequency control (d)SOR convo! +Automatic VAR contro! «Automatic power factor control {e}77 comrol »Automatic heedweter level contro! +Automatic flow rate control (f)High efficiency control «2){g)Various program operation (h)Joint operation (3)Seq fa)!plete start/stop sequence monitoring {b}Main machine status conditions (2)Controi funetion function (c)Aux.machine status conditions (4)Remote (a)Controi signal receivingterminal(b)Numerical setting veive receivingunit(ce)Supervision signel transmasionfunction(d)Massunng signal transmission Remarks °1)Used together mth magnetic relay emergency shutdown circuit. *2)Impulse turbine,Kapien turbine Fig 1 Total Digital Control System Block Olegram Quaeeey Conre wwmre?anLa wemerce to<' warempOwescowe . ' ' Conve .cme ||{ oy ett Table2 Functions of Digital AVR Table 3 Functions of Digital Governor Function Contents Function Contents Cross current compensation Prevention of VAR current from Characteristics Deed band:0.02%«1} flowing into each units when 2 or more Gent time:Less than 0.25 sec 01) generators are in Derallel operation Range of adjuntments Speed:90 to 108% Fieid current limaing Generstor tieid current limit in brushiess exciting system Minor control toop with a feedback signal of the fieid current Time constant compensation in dDrushiess exciting system Frequency compensation Synchronizing signal compensation against speed rise at load rejection Permanent speed droop:0 to 10% Momentary speed droop:0 to 50% Time constant of damping:0 to 15 sec Basic calculation PIO operation (with 65F and 65?functions) Wicket gate opening control Wicket gate consuant opening operation (77) Water level contro!Upper reservoir constant water evel Smooth voitage build-up Voltage overshoot contro!at selection operation from field flashing to AVR operation Output control APC.AFCReactivepower|Leeding Prevention of stator core local overheat Power cutout Load distribution operation during parsilelrestrictionLaggingPreventionofrotorcoiloverheatstadiecontroloperationof2ormoreturbines Generetor AC current Prevention of stator cod overhest High efficiency Optimum runner vene opening (Kapanrestrictioncontrolturbine,Bulb turbine) Frequency drop Overexcitation compensstion (high paises the number of needles usrcompensationvoltagesync.onty)of main trans-imputse turbine) former in tow frequency Automatic soeed Function of automatic synchronizingAPTR,AQR (Q ©28 +bp)requisting device (#15)Automatic reactive power or power factor requiation Line charge Line charge PSS oP detection system Manual voltage reguistion ACR system (Detection:Fieid current) Automatic follow-up control Automatic foilow up of manual signel Automatic voitage beiancing Function of automatic synchronizing device (#60) Fig 2 Digital AVR Biock Diagram +seme me -vm > Otpen AVA |atnateetamtednerem -i||be +33 aniCO aOror eeae ee Ped iiAutomatic followup contro! Fotiow-up to 65F to 77 during water regulating operation (77) Over power restriction Restriction of over-power Soeed droop operation Comouting speed drop Soeed relay 13,14,Tab 02) Remarks °1)inciuding mechanical controt unit *2)12 is installed seperately Fig.3 Olgital Govenor Block Diagram =o Ogw gewew Oews.|>Fremverey (236)le OQ nen Wenet ge comuneEttecweecorner Cowes Oramearay cannesWate:qu om +Waa qne enemyqwonueanveaura-+Sanne orenercommer +$eus comestowserwenOvesewet4+Uecove someou'gum Rosdh."io)f 3_ eneww ,cmtatadendl i Lemacg|+Wetet gee wong Toren Gow quateVerotng, mead +tenet mamterengtereng+Onioet engSa!geprent Fuji Electric Co.Ltd. 12-1 Yurakucho 1-chome.Chiyoda-ku.Tokyo.100 Japan Phone Tokyo 211-7111 , Telex J22331 FUJIELEA or FUJIELEB a.iam weches om ah contin..©mms Pr Wield Sal 2-2 High Reliability Design (1)Basic Concept Two basic approaches for the improvement of the reliability of control equipment are as follows.© 1)To build up the faultless system (prevention of failure). 2)To prevent the effect of failure to the whole system (minimizing the effect of failure). And our concepts of the redundancy are mentioned below. 1)A system which is capableof self-diagnosis should be duplexed. 2)A system which is difficult of self-diagnosis should be triplexed. 3)A system which is difficult to be multiplex should be not concentra' (2)D-EHG system configuration The D-EHG system is built with the following configuration: 1)Main Processing Unit (MPU):(Fig 2-1-1) Be triplexed,because it is the most important part of the system, and the self-diagnosis for computed results is impossible.. 2)Control power source supply:(Fig 2-1-1) Be duplexed to assure the control system,even if one of the lines is down. 3)Input/output unit:(Fig 2-1-1) I/O unit is duplexed commonly to 3MPUs,because self-diagnosis is possible. _AO (CHRAO)(Fig 2-2-1,Fig 2-2-2,Fig 2-2-3) AO is duplexed (or "OR cannortinnl haa-----_e. khen a failure is detected in the A0 card,it is turned off and Simultaneously the another AO card oa standby is on.: DO (Fig 2-2-4)Ke Same as AQ. _DI_(Fig 2-2-5)|< Same as AQ. But some important i/os mentioned below are triplexed and directly connected to MPUs. Triplexed PI -Input of turbine rotation detection (Fig 2-2-6)e Triplexed DI (Fig 2-2-7) *Input of 526 -Input of turbine trip >Input of PT fuse blow ¢Input of turbine starting system Triplexed 00 (Fig 2-2-8)|® *Output of turbine starting system Triplexed AI -Input of control valve opening detection (Fig 2-2-9)|@®-Input of generator output detection (Fig 2-2-10) -Input of WT ITM(Interface Terminal Module):(Fig 2-1-1,Fig 2-1-2)|®Be sisplex for each i/o signal,because of duplexed I/0. Input/output serial link (T-link):(Fig 2-1-1) Be triplexed because the MPU is triplexed. MPU serial link (P-link):(Fig 2-1-1) Be duplexed. PUTA SHELFaePo)RIGAl | PU-B SHELF PLAaoenatioan"TAr)fa]emaoons Se,easPura SHELF PLA |ese cacaca es pROGAAreLT NG A AM. Sm mmTete atiaes A Tera SO te we we ee ae T-L Int . ate?s£-9 t/ort CELE fect SELF=ica}c]c|ca EG as |Full Electric ,}c)dec.15.1 orate Ya Revised .27.19.'87 AND POWER SOURCE CONSTRUCTION ROC)|eRePoyjem"l_el i A f !AMAA ff i GB GORGE x7 "toleaa iC =-Flas.ryem ----4 SRP PPP PP Ppp poo eee vaca wer BE Oo @ BEETS Se ae rd Outline The stability of turbine governor for Alaska Power Authority,Bradley Lake Hydroelectric Project was analyzed using a simulator.(SHYTAP) As the result,the setting of governor constant in Table l was determined appropriate,as follows. Table1 .Governor.Constapt Constant Name a et Value. Power Output 20%70%90% Proportional gain Kp 1.8 0.7 -0.9 Integral time constant Ti 10.0 20.0 20.0 Differential time constant 'Td 1.1 1.1 1.1 Droop bp 0.03 Condition for Caiculation 2.1 Governor function is shown in Fig.1,block diagram. DEFLECTOR/NEEDLECURVE +CEFLECTORric;100 cE ™ 776 {Ts92.2.0 6SF..4 ol Kp +ff +.1]NEEDLE NOIALA,+AJ -\100 Ts >7 +{70.1 Tsn 2600 N *LIG 6o +q [3s :.NEEDLE NO2 NOS +Ls +Q03 k-=fre NEEDLE NQ2 NQ6 65P CALCULATION OF TOTAL OPENING FOR NEEDLE FIG],BLOCKDIAGRAM FOR GOVERNOR 0696S -'1- BRADLEY LAKE 7S CASE R-4-2 am">t=: Sy ees a3 23S13 ev a MAliwo es are ae s<|- = Slay zz QRwsg |oe <, 7ipRB aa pit uJ eo ".' :!x OyIoa it} Py 4ae :i:ra” " = :of ES > trot ze :i$ an fos t go eePik x on that tat S ::i|g joo Piri TF ig tl =z_& >:ft onoPit$BBMS:i! nod cio nua : a] on wun ,AY= ' LBEre ' a e La) H ' :e:raes!ilg: N so!ae!ae! LS : ™N . rae . a=! {8 TO aeaea ee ae PS 8 wea aaarztztss22=4- = SabianPtrell9 Mp OR amore sts' 3[=] (4) NBS g gS 22 ” ° ndS; wo (41 9d8 g8&333ag2°=zoSo fo] o (yng 8 BEE ai (4) LlOs EY3233¢a&45 ita 4 qe. (4) INSQ” 8238¢®g25 rit - : on eepawinangseeacay < eae tidy A " 2L }aalMSs;| Sid: 3 a Q -° -Lt 98 !. " a :* os oF i 7eee mi riyia 4 a : Cy we Sra fe|: H <a aH A aHie 2 bar ° : 3 3 S C] LE:@ |OPT.© iS oO | . ra RTT >2 w is al .©olely gy 1! $ pe . "7é titow if eSo s Ar<7an It.Ss ! i oo = 7 4b: Segoe ||| . |=e | Lot TT.i+ red beryl otiebonieee . T_ijiy .{14 :ql La ' CeA Pea ioe a er | | ae Prey tetas i!| ii ann Leiba tate Epida irae | r - I| can hotores tt | PALE OUUSCU Tere or | YW a REEL aVAGSEIERE / Aii.Mile| |aonRle}e ' nit 4 a 1on Anne ae TT PA TELE 2 Try _oY BEoReLgh. a iV: , 3 '| 3et.| Fiatdg;3oO' a Clyp og) . ay ' BPEL Jibradi ve) | A = PUL: Lii3 4 | = BRETT| oe BY aa Ji! 8 PTT T/TTPEta deofes ; oe a | = - . w =Bh ; tly"7 s |Yi|ie ' Jt rt =ean |||: L an : rs|||||{iLy at: | TPIT ATTN rt cat :i) 1 ! eee Ijt PLRSmj|||\ Lil 1| | boi}! i L !: merL Ey, SUD = ! ! : womeney Ce ee ee ee ee ee ee ee eeBeeegeSoeeee " A CASE Jorja |CAS@ 20822 ; --|-" oe ee eer ee eee ee ee et ee ee ee ee ed i es ll M a ry SSee re -seeroe 88 tee em mem cmmee meeeso eneaee ene nomena rsi .QO wr _S Cr ee a a SS een iS Ar 075 ee »ADO Octs More 4 i0%LoAd||2 a Fuji Electric Co.Ltd.|2 i Fzz 4 : T al a fF.|o 9°'4 E /'° +com|---J CASE 20 032 3 j = =) Li |HeWA Ss THT TE IEE |}cf i5° Hy oe ane HIS § 1 : le: bY! le "* LT\ys .: Ah|i," = }}> Nis}|be- la3 (AN . \a |g vi oe 6 fire ||2 & Y s" 1feFS \ Rims o =7a a !*;;;;-77;:ee: ire if, - - a | a Pre || | suaeas RESERRSSROOROROAE RIRBAERAIT | 4 pry: etottip \ otedt x ly A| ona tba ht! a ) ofrnen : "nnn 2|'|' ELTT EY HETEERE ELE AEP apeereannnly< rid | ZA |- ey TATYT Lil 3 i|ae wie Anatee aa ohyy PATELLA ETL[te | SLY min Mydiyeeya ah, ¢ mi yids || $M:4|1}ib ity. a a a fi RET fly = - VA yy | ce LH RESEE)/A00Es Hi ftta | C1 Ld INiy an || ue. '| Hie | Sgi11|S Sanne ;na|lTl ain ilTyahl| EidPldtty)pe = T T ACASE JOTQI L-Snes eennteee ener nennen .tm,dr "4. ree ee: i)"aI= ACASK Tol Ir ee ge ewe Sa ee ease 7or22 ;ae meee H--JcASe JoT jr -|e nee --JC)a -|---| ome R11" : -}--* comets oo Gs A agg gns tM tes spemeemenrmecnmenttmee,wo .. awe4 --|---JL \'i af| .id oe]ope o +-.-f 2,« cr Pr a J efwoofosbeecoteeeee80eeeoe---aitretie netted :3 rene a -,x Pee ee qd cASe 70023 i QS re i <eee 4 =:'SS aed a x3: "mann i '|we *Kp "14 -Ta[en0/0 2 ee 1°}-;- *:Tt:t -NN,::: Se NO el __|-SS : :SN.-_4 _.-/'Ss :\oe mee eee fi cere .Ll er ee ee ee ee =F aN |YF)WAN 9 Cee Morne Fujl Elactric Co,Ltd.Tite70%LOAD Dung,Mn.-e.'Eét_b06TOe4y J Bfbales -CASEQOD3. oe 8 Ss &&8 @aeeeSee ONE 2 ere nt E9002] LAr as EP"Ss &&&8 oe 8 6 TCASE90622 =wT Cr ef yywaleas 2]5] LO 90%L£0AOFujiElectricCo,Ltd |8 CASE G00 12 cy »LJ «[J e *e os a a 3" on amyfehafotofow}Ce ee ee ee ee ee ee ee oofaob.-ASetteWigeeeeLetsear:ae:hy7 case goraa 7a ey 2 0 a ene"a 7- [Y--_=Kp= 0.8 LN _U Fig&rae | he 225707 Oate (7)Z CAO {"3, Senet Fuji Electric Co.Ltd.|?9 %f Z o 8 J a 3 (24)4)SOTs&70]70 60 |60 $0]50 40}40 30 |30 20}20 (Mm)SH13 370 360 350 340 330 70 40 10 Ln Tite ca eee eee meme OSTheeewewtertmem SO $00 vr150200250300350400450500 "ime fbr CO2=aaenme TMM =21.87 M3/5 PCE=59850 KH H =358.32M O N =300.0 RPM Alaska Power Authority BRADLEY LAKE SCHEDULE COMPARISON 19867 1968 19890 19900 19901iJ|1 |J ||1 ||T T ORIGINAL SCHEDULE UNIT 1 isaue ON-LINE 810 OPEN Fata Fue UNIT 2 o0o0c siI08 NTP RESERVIOR TUNNEL on ast ert 7706 est 10/0 1249 O78 E-T ygynKphnpnpnpp III "aM bactas REVISED SCHEDULE (3/13/87) reoue oven FULL FILL |«6OUNIT 8 UNIT 2 oe tek we a i F-4 SSG iiAUIUAAADIAAGAA|31 Mo La 24 PROPOSED SCHEDULE (SQUE CALL OnBIDFOROPENFILLFILL UNIT2pocBIDSBIDSNIPRESERVIORTUNNEL\on oe $4916 «67080 6741 test 3/t vi yEAHFHHTyyyFFIEEEEEW'°*W”vv F=E=e7 [.a2 Me |be 12/67 Bradley Lake Hydroelectric Project PROPOSED COMPLETION SCHEDULE CONSTRUCTION GENERAL Civil CAMP &CATERING POWERHOUGE TAL CLEARING TIL CONSTRUCTION NURA/MIDOLE FORK DIVERSIONS BITE REHABILITATION PROCUREMENT TURBINE /GENERATOR BCADA 1988 1989 1890 1001 2 Bid Notice tea Proceed ec Opening (NTP)Fil Reservois Fur T esese?x i a aera mn oe tL -y |ey 7to«atJ wre 37166718 0716 Leley j a noteil are Embedded Parie testiegontOss10708viteore --b ¥¥ aie |Conctrvction } utp 3/18 6/4 O78 ¥£aie)|| vp Gst)Fee ost to |eles Procurement ||Construction } wie s2as06 ase 4st | uve ast ot tere¥bd y4BieShipeq{ Embedded Gale ant iid Parte Turbine/Generater arts 3716 os06 _-¥_¥+ BI Fabricete |taotall aad Test | amt a 6 isLateid|Procurement ||tnetall and Feat ] tase? oeo=e 2 a >Alaska Power Authority PS Pg &8 Prd &x AQBRADLEYLAKE©@ 9 2 A ey+f/tHxr/«<$CONTRACT TARGET E %a 2 JDATES©°+2 e o & GENERAL CIVIL o/esa7 |6/16/08)7/1788 N/A |3/9001 |orssot t CAMP &CATERING 3/16/68 |8/16/08)6/16/88]NVA N/A 0/1/01 3 9TURBINEGENERATORN/A NIA |9796708 |eee]arsros |otros0/16/80 SCADA 4/1408 |6/16/88]7/16/88 |1980 wisot |o7tso1 POWERHOUSE 6/tsee |9/1/68 |10/16/88)NVA 1/9791 |osss01 T/L CLEARING 3/16/88 |6/1/88 |6/1/08 N/A NIA 1/1/80 T/L CONSTRUCTION 6/tse8 |7/1/08 |estsee |1080 NIA 0/1/00 NUKA/MID FORK DIVERSION |jo;s8;89|3/1/00 |4/1/00 NIA NvA |10/1790 CONSTRUCTION SITE REHABILITATION 2/1/09 |47791 |6sts01 N/A NIA Tatseves '7 Attendance: Dave Eberle Oscar Johnson TECHNICAL COORDINALING COMMITTEE GOVERNOR AND SIABILITY SUBLCOMMI ITEE BRADLEY LAKE HYDRUELELCIRIC PROJECI MINUIES WEDNESDAY.JANUARY 1!15,1988 (At the Alaska Fower Authority.Anchorage) Alaska Power Authority Alaska Fower Authority David Burlingame Chugach Electric Association Bradley Evans Danial Rogers 'Myles Yerkes John Yale Ron Krohn Chugach Electric Association Chugach Electric Association Matanuska Electric Association Stone and Webster Engineering Stone and Webster Engineering I.Purpose of the Subcommittee Mr.Yale distributed the aqenda to open the meeting.Ihe purpose of the subcommittee is to discuss relevant issues regarding the unit governors and their effect on system stabilitv.Also,this subcommittee will address relevant issues of system stabiiity in regards to how the project will effect the system and how these erfects will be handied.this purpose of this particular meeting 1S to discuss the features of the governor to be provided by Fuji and familiarize subcommittee members with the hardware currently being proposed.ithe agenda for this meeting is listed in attachment 1. tI.Overview of Proposed Digital Governor. Mr.Yale distributed a Fuji brochure,attachment 2.which describes the Fu }1 digital governor.He then distrubuted attachment 3.a block diagram of Fuji's digital governor and a description of Fuji's philosophy regarding reliability and redundancy. the governor is based on Fuji's MICREX-FS00O Proagramable Logic Controller (FLL).tt is based on the Multibus II bus.All components are on plug in cards mounted in 19"racks.lhe governor utlizes triplexed main processor units,and duplexed input/output hardware and busses.Critical inputs/outputs such as unit speed.unit trip command,etc.are also triplexed. ihe arrangement being considered for Bradley Lake will integrate the functions of Automatic Voltage Regulator (AVR).governor,and the unit start/stop logic in the PLC.Fuji is currently completing work on their prototype for a similar hydroelectric project utilizing this three function integrated arrangment. Fuji has furnished approximately 70 installations utilizing digital governors in steam and hydroelectric applications. However,they are not fully integrated applications. Mr.Yerkes suggested that Stone and Webster obtain an experience list from Fuji on the application of their digital governor. Amoung the information sought should be a list of digital governors an North America,case history on their service records.response times by Fuji to service requests,and mean time between failures. Mr.Eberle stated that Fuji would be testing their prototype of their latest digital governor which would be applicable for Bradley Lake.this prototype 1s being furnished to a Japanese utility.Mr.Eberle offered to send a representative from the subcommittee to witness this test if the committee thought there would be any bdenefit.After further discussion,1t was agreed that this would not be necessary until the factory testing of the actual Bradley Lake units being furnished. Ihe discussions ted into software programing for the PLC.{t was stated that programing 15 similar to PLC's made by Allen-Bradlev e. and General Electric.Concern was raised that the Owner /soerator entities need to be able to correct software errors without having to depend on Fuji.Questions were raised relative ta now much training would be received trom Fujl.itema such 45 software,training.and spare parts wil!be included 1n @ change urder to the contract to Fu):. fil.Governor Stability Sudy Results Mr.Evans of Chugach requested that Stone and Webster supply hiin with the assumptions made during the performance of the ioad flow and stability studies made in late 1985.Mr.Krohn will send it directly to Mr.Evans. Isolated operation of the Bradley units was defined as operatiiig without a Gas turdine connected.{he normal method of this occuring 18S for the line between Soldotna and University to trip. Since this can occur in a multitude of locations,there may be a need for Chugach to develop a SCADA siqnal to automatically indicate this condition.It was suggested that in lieu of a SCADA Signal that is dependent on 4 to 10 second scan update times,it mignt be prudent to detect this change of condition based on the size of the load error signal.Thas item will be further addressed bythe SCADA subcommittee on January 14,1988.It was also noted that while operating in this isolated,isochronous mode.that the Bradley Lake units cannot control frequency. Mr.Yale distributed a submittal from Fuji on the aqoverning stability,attachment 4.It illustrates the modei for the governor and indicates response characteristics based on standard [EEE parameters for load cases specified in the turbine generator contract.ithe diagrams illustrate the need for a variety of governor settings based on the load condition and on whether or not the unit 18 isolated.the easiest way to implement the required variety of governor settings is by use of the digital governor with software change of the settings based on the inputs toa the governor. ihe cases studied to date were arbitrarily selected by Stone and Webster based on experience.fhe utilities need to advise Stone and Webster of their recommended assumptions for Loads.toad changes,and acceptable transients for future governing stability runs.Additional items to be addressed by the utilities are tne identification and clarification ot loads to be carried during isolated operation and the point of disconnection to be assuined as this will effect the load. Mr.Eberle added that the discussions so far had addressed only operation of a single unit under isolated conditions.He indicated that the chances were that both units would be operating rather than just one.Mr.Yale responded that although that may be correct,the worst case for stability is with only one unit operating.therefore,:f we can make one unit stable, both unzts will be stable.[wo unit stability will be examinea as part ot the studies for the non-isolated condition. Ihe discussions shifted into experience with the lerror Lake Project and it was pointes out that simple system actions such as reclosing small loads had devastating etfects on governing Stability while operating isolated.Similar concerns were espressed over the Bradley lake Project operating isolated.lhe criteria used for the stability studies by Fujl were for 3% maximum speed change.It was pointed out that this would effect the low frequency ltoad shedding scheme.these trequency excursions would cause automatic load shedding to occur,possibdiy agrivating the stability problem. Additional information on irregular loads will be required from HEA.especially relative to large toads such as the 250U HP motors at lesoro.Information will also be needed on large lvads at Seward such as the ship lift and the coal handling faciltiy. Infor mation needed will be freguency and duration of operation, type of starting equipment.and any agreements that inay be abie to Limit the operation during isolated conditions. lt was suggested by the Subcommittee that APA should undertake an overall system stability study.lhis is based on past practice with the intertie and previous projects.APA could serve as the interface between the utilities to accomplish the required program.Mr.Eberia could not commit APA to such study without knowing more about the scope,cost and need for the study.APA did however request Messrs.Krohn and Yale to davelop a Scope of Services for such a program for review by the subcommittee.Such program will be in generic terms,not necessarily for performance by Stone and Webdster.Ihe Scope of Services should include many contingincies and should define end products and required computer stability runs.It was recognized and recommended that Stability runs be performed using the readily available EPRI stability program.fhis program is a good model for transient stability,but is good for only tha first and second power swings.lt will not provide results for governing stability. the qroup agreed that use of the proposed digital governor would be acceptable,subject to favorable response from present owners of Fuji equipment on the questions raised. IV.Ad jourment Meeting was adjourned at 11:15 A.M.Next meeting will be sometime near the end of March. Ve Actions Required Action #13 Stone and Webster to solicite information from Fuji and utrlityv users regarding digital governors supplied by Fuji. Action #2: Stone and Webster to report on Fuji digital governor prototype demonstration in Japan on March 7,1988. Action #3: Stone and Webster to prepare scope of services for a raiibelt system stability study.this is to be distributed for review In advance of the next subcommittee meetina. Action #43 Homer Electric Association and City of Seward to provide data realative to irregular major electric loads as discussed relative to isolated operation.Stone and Webster will contact respective parties to clarify the information required. Attachments: 1.Agenda Ze Digital Control System for Hydraulic Power Station -Fuji Electric 3.Governor Block Diagram and Reliability Criteria -Fuji Electric 4.Governor Stability Model and Simulation Results -Fuji Electric ca AGENDA TECHNICAL COORDINATION COMMITTEES GOVERNOR AND STABILITY SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 13,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Purpose of the 'Subcommittee II.Overview of Proposed Digital Governor A.Arrangement B.Hardware C.Software D.Advantages III.Governor Stability Study Results A.Results to Date B.Information needed from Utilities for further studies IV.Adjournment 3603R/CG at 2 SUSCIIUIE Digital Control System forHydraulicPowerStation .=Wg 22}.oN.==ae,Ven ie irs yt New Technologies for Hydraulic Power Plant Applications Recently,a programmable controller (PC),a digital control device incorporating a micro-processor,has been put inpracticaluseforbroadapplications,rather than using con- ventional electro-magnetic type control devices,in order to provide higher reliability and simpie maintenance of hydraulic power piant systems. The programmabie controller.is capable of high speed transrmnission of large amounts of data through a dataway as well as multi-function processing and high speed conputation due to the rapid technical progress in the field of PC's coupled with developments of new peripheral devices such as a CRT display. The MICREX-F500 having such festures is designed as a total digital system for hydraulic power plant systems;and is being used not only in conventional control but also for hydraulic turbine governors (hereinafter called "governor''),automatic voltage regulators (hereinafter called AVR). This programmabie controller is highly efficient,economical and reliable. Advantages of MICREX-F500 (1)Adoption of unit type hardware and software for added functions has resuited in 3 compact device embodying enhanced cost-performance. (2)1/0 units can be instailed in various places where data are concentrated so that data can be collected by using a simple cable route. (3)The MICREX-F500 can be used not only for a newly installed hydraulicpowerplants,it can also be used for replacement of existing control systems in such plants. In addition,it can bs used in combination with 3 sequence controller,exciting device or governor. {4)With incorporstion of an operstion penei,full scale man-machine interface functions can be accomplished. (5)Use of intelligent Al cards eliminates the necessity of transducers for external analog input/output interface. Functions of Digital Controller for Hydraulic Power Plant Table 1 shows the major functions of the digital controller. Fig.2 shows the functions of the digital AVR,and Tabie 3 shows the functions of the digital governor. Table 1 Functions of Digital Convoiler Function Tvyorcel exampie (1)Sequencing =(a)Saartuo ena stoofunction(b)Emergency shu towne1)(ce)Normei shu mown(d)Automatic ching of h(e)Automatic recioung (1)Aux.machine control (a)Automatic voitage reguiator contro! (b)Governor speed comrol (c}6SF,65?controt sugply syrem (2)Comrot function «Automatic power factor contro! {e)77 comrot «Automatic heedwater level controil «Automatic flow rate control (1)High efficiency contro!«2)(9)Vanous program operstion (nh)Jome coersticon la)incomptete start/stop sequence (>)Man machine status conditions (ce)Aux,machine status conditions (4)Remote (a)Control signal receivingterminal(b)Numerical setting velue receivingunig(dd Supervision signei transmmmionfunction(d}Meneuring signal transmanon Rermercs °1)Used together enth maqnene retey emergency nuwown circuit.°2)trrowies curbine,Kapien turtune Fig.1 Total Oigital Contre!System Bleck Diegram26Tenemese©ae ame:emawe-+---_--< . (3)Sequence monitoring function Table 2 Functions of Digital AVR Table 3 Functions of Digital Governor Function Contents Function Contents Cross current compensation Prevention of VAR current from flowing into eech units when 2 or more generators are in oereilel coerstion Field current Limiting Generstor fietd current limit in dDrushiess exating system Minor contro!ioop with 8 feedbeck signal of the fieid currert Time constant compensation in Drushiess exerting system Frequency compenstion Synchronizing ngnet comoenstion against speed rise at loed rejection Crarecteristics Oeed band:0.07%«1)Oest time:Less than 0.25 sec 01) Range of adjustments Soeed:90 to 108% Permanent speed droce:0 to 10% Momentary speed croop:0 to 50% Time constant of damping:0 to 15 sec Basic ceicyiation PID operation iwnh 65F and 65P functions; Wicket gate opening contrat Wicket gate constart opening operetion (77) Weter level contro Uooer remervor constant water level Smootn voitage buiid-uoa Vottage overshoot conroi at ssiection CoesrstiontromfieldflashingtoAVRoperstionOutwutconuclAPC.AFCReactivepower|Lssding evention of stator core locs!overhest Power ouwut Load distnbunon operstion Gunng paraiieirestrictionLaggingPreventionofrotorcodoverheatstablecontroleperstionof2ofmoreturtines Generator AC current Prevention of stator cod overnest Mign effinency Ootimum runner vene opening (Kapanrernetioncontratturbine,Bulb turbine) Frequency croo Qver-excitsnon compensstion (high Seiecning the number of needles usedcompensationvoltagetync.onty)of main trans:limmuise turdine) tormer in low frequency Automenc speed Function of automatic synchronizing Automatic reactive power APtR,AQR (CQ =2 +dp)requisting device (#15) of power factor requiation Auromane fotiovweup Followup to 65F to 77 dunng wearer Line charge Line charge control reguisting operstion (77) PSs OP aetection system Over power restnction Restnction of overpower Manuel voltage reguistion ACR system (Oetection:Field current) Automatic followup contro! Automatic fotiowwvo of manual senal Automatic voitage Daienang Gevice (#60) syncmr Fig.2 Olgitel AVR Bieck Diagram Otpen ave i-iiISoveddroopopersuon Comeutng ipeed crop Sowec reiay 13,14,144 02) Remarks °1)inctuding mechanical conret unit°2)12 is instaiied seperately Fig.3 Digital Gevener Block Disers: coms Octes et tagwtlesiouta E313 Ns 40 W3IBIFNs LECTS xoLILZEL?CAROL '@uU0UgURdESOO!OAM]'NY-EPOAIZD "BWOYD-;OWONABINA 1-71PIToDouye1gIIn4 =! 2-2 High Reliability Design (1)Basic Concept Two basic approaches for the improvement of the reliability of control equipment are as follows. 1) 2) To build up the faultless system (prevention of failure). To prevent the effect of failure to the whole system (minimizing the effect of failure). And our concepts of the redundancy are mentioned below. D 2) 3) A system which is capable of self-diagnosis should be duplexed. A system which is difficult of self-diagnosis should be triplexed. A system which is difficult to be multiplex should be not concentrated. (2)D-EHG system configuratioa The i) 3) D-EHG system is built with the following configuration: Main Processing Unit (MPU):(Fig 2-1-1) Be triplexed,because it is the most important part of the systen, and the self-diagnosis for computed results is impossible.. Control power source supply:(Fig 2-1-1) Be duplexed to assure the control system,even if one of the lines is down. Input/output unit:(Fig 2-1-1) I/O unit is duplexed commonly to 3MPUs,because self-diagnosis is possible. AO (HRAO)(Fig 2-2-1,Fig 2-2-2,Fis 2-2-3)AO is duntlavad /.-4AM ---.--*° when a failure is detected in the AO card,it is turned off and simultaneously the another AO card oa standby is on. 00 (Fig 2-2-4) Same as AQ. OI (Fig 2-2-5) Same as AQ. But some important i/os mentioned below are triplexed and directly connected to MPUs. Triplexed PI *Input of turbine rotation detection(Fig 2-2-6) Triplexed DL (Fig 2-2-7) -Input of 526 -Input of turbine trip -Input of PT fuse blow *Input of turbine starting system Triplexed DO (Fig 2-2-8) *Output of turbine starting system Triplexed AI -Input of control valve opening detection (Fig 2-2-9) -Input of generator output detection (Fig 2-2-10) *Input of &T ITM(Interface Terminal Module):(Fig 2-1-1,Fig 2-1-2) Be simplex for each i/o signal,because of duplexed 1/0. Input/output serial Link (T-link):(Fig 2-1-1) Be triplexed because the MPU is triplexed. MPU serial link (P-link):(Fig 2-1-1) Be duplexed. cu.6l JUN pds lAary W cence cee pep UEP SNL JIUAOS UU ONY .eruyo i9'ST°2299 tuetgee Fg Y Bl prog opyoatg ing mar q ol Sowa 13-0 pn 3x1v0 OFSIASY JUV S$IOUTIOS UMOd Lesetoi nvr eer INPwVRN SUITS EOS FO)°41 ¢vnire > tanWw jnjoel SEE BOY OHO 'a!! cape Wott pret wpisAs *ant |PE OD ¢'¢¢9 twanePIPETTEJevaaead"rT pape Ww {NPI DerrmA '564 | ay uf et en os ee es ees Qs es ee ree es ee+L£water ore me gm eamme ai a -"ge88Depre wns vosswenopmogs we avy ga asine |f g aaa ELI 1 Hf HEI Ey iSOEe|I eR Ee||GIGI GI EA EA eA ES WHE T-d |wee eee eee LL ee eee LeLmi@ memes 8,wy wore 2. 0696S ? Outline The stability of turbine governor for Alaska Power Authority,Bradley Lake Hydroelectric Project was analyzed using a simulator.(SHYTAP) As the result,the setting of governor constant in Table 1 was determined appropriate,as follows. Table 1 _Governor Constapt Constant Name Set Value xienienats a Power Output 20%70%|90% Proportional gain Kp 1.8 0.7 °Q0.9 Integral time constant Ti 10.0 20.0 20.0 Differential time constant Ta 1.1 1.1 1.1 Droop bp 0.03 Condition for Calculation 2.1 Governor function is shown in Fig.1,block diagram. DEFLECTOR /NEEDLECURVE r aa +100 1 OEFLECTOR '776 =}aon 20 65h +Kp tof +.7]_NEEDLE Nox --+AJ -A O 6 S.i +(Ql Ty"2600 ee zt |NEEDLE NO2 NOS omq03}+--»zi 65P CALCULATION OF TOTAL OPENING FOR NEEDLE FIG],BLOCKDIAGRAM FOR GOVERNOR -'1- M-NEEDLE NQ2 NOG SRADLEY LAKE PYS CASE R-4-2 a+=» ;-ss! Zs 23 S-2. = ss Sit!"SsS-S i = 52a z= ZaSisfi pS 3t v4iigPe}om¢ry'yj w :t ele x toa =e i$ as soa - am a't aN i' Mout:4S:ilg |os ri Tsie i! z2 | >war 4 ono Pt pB1B%S ia |* |&s8 : mwa . we to4 wun en 3 oa2 jazz fhoAbs!lo&)LSNSsro™ DPtae b aeStesi+8zoe.ereS| 7 i} (4) NBR bo g22 bd ”Ss (41 Odg R3=33:a&=°S |22=5 -= ao [ ] oS =- el tHe&33gPS=-| (41 108 z323333g2¢ = '' (4) (NS3 83&333mR&2 poi}tIl SS «|*eS||ee=vali ome ce ::°.:soe wg |CASE 200 2!°me,ne ee ee sores ee wre Pe soe :se .¢ .se ae : <=OB !---h ---f-=r + }\ 4 --|-- --|------4 case 200 ito:ooemteait”(o 1 CASE 20022 o comeof CASE 200 32 . »Ejoyetnweteermals:2sons, 'A VAN LNS tN al aten ee wy f s é i i aieae\.a wee fae haa 6-02 meee'.aw Trees EVES nn oe Tae gape sles ok lores caryos amis eT .-.[--=-_-eee ---f----_..993 ma cram ee Te ess Petty-ire S =NX -Tr $ TH 2 et 00 LT 0 ST sae -= -1 rinea*xRieDeve Mens 0 So Z0AD|-<j-Fuji Electric Co,Ltd |Ret[OumnoNXtifit3-TTnT7+T oo 7 Oe atta ,* Tn : | A||| ce ee er ee ee S". 0) = _S§ wee - ) . ;NS ob - : Cwtng)I0y cae|YA 4 : 1 1: : ate - : Dt $ ii'TVA|| UY | A Y\|- 5| i < ' HY . i flts on. | "fe fe | 1fy 1F _* J is tdi : 1| t , ii | BLE HAP ELEE UA PELL Tg ' a ie|Abo RL. "fd Ty Lids neice anon S i - { 'ii i | S | | HES+ i1 14 he)tT je \ an Pie|oa& oq i es ! ej: ad \ ». i||= oe / eS i 'lis z P. a P2 in ryt8 " e ' ie " .= rl: lS2 " yy "hd Li; aw iyad 9 ¥ ae ' aos ra!|a 3 3 Se OPI LS. a5 = ie Sees |||1 eS LL + ifte i pbb bhiareby ee} i iyi ' fitiil SAEEeEe ih : H fc: ' pan ' Ay triig bigeye! YEE i : A enenohAa SEeeenee ; Wee. Pf Ped|dled. , i: Lj : wie HLL) rap s 5i oe 3 % . ; }pol ' wile it| i nie mae é |i|: ot wy ' a .! 3ry'aie : LE) le ;7 : | ace | |: " .joebmde. oe ? ; 2 Wr: | it| : Ayr)|Py | ' | j jet A. -t mo oe : rt 1 4 ' - Se @ 8 8 6 8S tere 6 ew 8 te eee [or eer ee L AcAse 706 on WS om tee . ll |]{casé 20092 ed 7 #£da] «1"-_aah et?a 4 CASE 20 O3r Ce ee a ee ee ee ee Cr ee ee eee ee ee ee ". > 3 U aNeS --}-==aa al _ ny ----a eee "=i A Oe SO EJ __. =5 0 DX)0?)nen ae) Fuji Electric Co.Ltd |s 70 Yo LOAD J n a LJ aAe€ FaySF'-T Bier ies!gaye "--aien-_,eee clatt3seegee||e --_= =|=e iw mrtg) jew 70%LOAD EitbFullElectricCo,Lid |f o OT ACASE Tot tr et ee ee et ee ee ee ee | Se ee a ne ee ee em ee -_-e bo A | m : | > = 5 ' a ||| a t a . < . ae = ' ry, . itt tei ft 1! |:"f. i} pote . { P ca| . 'oad : . ;inedi, i| [I+ 1 rill ii1fe! i if ; hay iy i : 'i ' : H wy esi .! eerie : el| i : a a le ' e;]- je-i|t le ; ' i le” ey: r= -¢ . 2 ilies pf:8 e 2} im- '8 rig .™ ba PUT]. D ei, a Soy TL Rl:2 _-- . ---- || :rs TTT Tt Tdtr : |: ww[a|i' ttf CT .8 8 0 . 1 a7 ee TT Ti| bly4 vo PEGEEEEE LEpeal beadey Jit perder tit Epa dy Pepe day : YPhebe tba Poof bint|playd Safad 1 rioike oe aefit fatadaDyddsyty 2| ! tj oe it 'jcasé 92021a er et ee i a ee a aleeeeegtwttwwl . JASE 9oaar Ce ee ee ee ee ee ee ee ee et-- 37 7.8 wT 8 8 Vas 8c a aTeae:ae ee COND ene aeee comeaFennheer 7 a4 its pins i ti.ii n Pyetr pst Nth :' roe §ar ee |No .i --heDee fo rT iy a ''e q t :pe 6 t . ''it ot . - :* --,a -Ce a ee ef F eae pal FE 0 10-0 1.- j=0%Lo0AO f 2 oj}Fuji Electric Co,Ltd.|9 70%.iW CE fi}7ae |0 Oo |Oe WE 6 re eer ements or lat hosesk,aia a,Sl ualee alcase forar case fol 12ya HEL{|-a a oe oo el errr nN oS oie _ST SS |nee eee ee ime i teenoe anf amge enngf t Dee we ee ---|-_____|]CASE_Qosaa | 'S ao 4.- :i aw Lone Fig8me| --- + Dave Nome ts)Zz OAO f , et Fuji Electric Co,Ltd |£90%J V 2 o 90 L a E 310 40 20 iL t4)40 10 CM)370 $50 340 130 At BPG40 PG 52.4% eee Ce eeaeTSTaaeeeweTO7Temeem=Tees meme meee ow we SE RH ETN mm mCweerwe ¥¥v v ¥=100 150 200 250 300 350 400 450 SOU So)Ls™Yine_(Stey£4PCE=$9850 KH Ci)2sauamnn Itt el 2358.32 H QO =23.07 NI/S "N=300.0 RPn Iv. TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY May 5,1988 1:30 PM Alaska Power Authority 701 East Tudor Road Anchorage,Alaska Adoption of Prior Meeting Minutes Approval/Modification of Agenda Subcommittee Reports A.SCADA B.Protective Relay C.Governor and Stability Old Business A.SCADA System Arrangement New Business 4639R/CG IV. AGENDA TECHNICAL COORDINATION COMMITTEE PROTECTIVE RELAY,SCADA, AND GOVERNOR AND STABILITY SUBCOMMITTEES BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY May 5,1988 9:00 AM Alaska Power Authority 701 East Tudor Road Anchorage,Alaska Adoption of Prior Meeting Minutes Approval/Modification of Agenda Old Business A.SCADA 1/0 List Comments B.SCADA System Arrangement Cc.Utility Review of Selected Project Documents New Business A.Stability Study Plans 1.SEI 2.SWEC Adjournment 4639R/CG >J ANCHORAGE CEA DISPATCH SOLDUTNA PLAN A BASE CASE SCADA-COMMUNICATIONSNOTE:ALL CONTROL/BATA LINKS THAU SELOVIA HECROVAVE SYSTEM TO ANCHORAGECEA DISPATCH fa -+-- 'SOLDOTNA | | :___BRADLEY JUNCTION[Rtv re= J FRITZ CREEK PLAN B HEA PROPDSED SCADA-COMMUNICATI 5 SYSTEM PLAN C BREAKER AT FRITZ CREEKNOTE:aft.CONTRUOL/BATA LINKS THW SELBOVIA MICROVAVE sw Fever,LUTE as | | | | | | | | | | | |PX BRADLEY.Lake -!HEA DIAMOND _I operations \RIDGE \vy\a FRITZ \leul \CREEK \|_al i €))ed es)---O-----\en BHF SELDOVIA PLAN DTeSaxSELBOVIAHECRINAVECOMMUNICATIONS L”" TERAaL TO HOMER Attendance: Dave Eberle Oscar Johnson Afzal Khan Don Shira Vance Cordell Bradley Evans Paul Johnson Tom Lovas Dan Rogers Steven Hoagenson John Huber Sam Matthews Tom Small Myles Yerkes John Cooley John Yale TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES Thursday,April 14,1988 (At the Alaska Power Authority,Anchorage? Alaska Power Authority Alaska Power Authority Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Matanuska Electric Association Municipal Light and Power Stone and Webster Engineering I.ADOPTION OF PRIOR MEETING MINUTES The Minutes of January 14,1988,meeting (attached)were approved and stand as written. IT.APPROVAL/MODIFICATION OF AGENDA The Agenda (attached)was approved without change. III.PROJECT STATUS AND SCHEDULE Dave Eberle gave a summary of the schedule for the procurement and construction contracts. 4587R/CG General Civil Construction Contract:Is out for bids;bids will be opened May 19,1988.Work should begin by July 1,1988. Transmission Line Clearing Contract:Will open bids May 4, 1988.Work should begin in June. Camp Catering Contract:Will open bids on April 20,1988.Work should begin in June. Transmission Line Construction:Will be issued for bids this summer with award late in 1988. Powerhouse Construction Contract::Will be issued for bids this summer with award late in 1988. Turbine -Generator and Appurtences:Expect to give notice to proceed with Phase III,manufacture,the week of April 18,1988. SCADA:Advertise for bids August 1,1988.All comments and decisions on arrangement must be made by July 1,1988. Iv.SUBCOMMITTEE REPORTS John Yale summarized the recent meetings. A. 4587R/CG SCADA No comments have been received on the SCADA I/O lists.CEA advised that they will provide comments by April 15,1988. Revised I/O lists will be distributed in June when the powerhouse design is complete.The SCADA arrangement and communications was discussed.A DECNET data link will be requested as an option,and dual CPUs will be required.HEA was absent so there was no discussion of their recommended alternative arrangements. Protective Relay Comments on the one-line diagrams have been received from CEA, and GVEA.Responses were distributed by SWEC.The comments by GVEA were discussed in detail.GVEA and CEA will review the responses and provide additional questions and comments. Governor and Stability The scope of the stability studies needed was discussed.It was decided that the most expeditious means to accomplish the studies would be through a contract change order to SWEC's contract or alternatively to CEA's contract with SEI. Accordingly,SWEC and SEI will prepare brief change order proposals outlining their plans. SWEC is still working with Fuji to provide North American references for the PLC that their digital governor is based on. Vv.OLD BUSINESS A. 4587R/CG Proposed Homer Operations Center Dave Eberle stated that the PMC needs to make the ultimate decision on the SCADA arrangement proposed by HEA.However,the TCC and SCADA Subcommittee need to evaluate the technical aspects of any proposed SCADA arrangement. HEA stated that they hired Black &Veach to evaluate Bradley Lake operation and provide operating and SCADA recommendations. HEA has a report including cost estimates.However,it is presently in draft form and HEA decided not to distribute copies at this time. Tom Small distributed two sketches (attached)of "Option A"and "Option B".Option A reflects the "Base Case"as discussed by the SCADA Subcommittee,Option B is the arrangement recommended by Black &Veach and HEA. HEA advised the committee that the Option A arrangement with the relay point at the Diamond Ridge substation and control by CEA dispatch is not acceptable to HEA because it breaks HEA's distribution system up.After considerable discussion it was determined that in lieu of Option A two additional alternatives exist.One is to move the relay point to a location between Fritz Creek and Bradley Junction.This will require a new substation,and an additional breaker.The other potentially acceptable arrangement to HEA,is for there to be a reliable communications between CEA dispatch and HEA operations personnel.This will enable HEA to maintain clearances and operation authority for the breaker,yet allow for CEA dispatch. HEA advised that with or without Bradley they are planning on putting in an operations center and SCADA system.It has been approved and initial work funded by the HEA Board. VI.NEW 4587R/CG Various means were discussed for communications between CEA's and HEA's SCADA systems.It was concluded that the location of the RTU to RIU interface for control of Bradley Lake was not critical.Also,a DECNET datalink could be provided for data transfer between the two systems. APA agreed to prepare revised "Option A"sketches to reflect the two possible acceptable arrangements.The sketches will be distributed in advance of the next meeting. Don Shira distributed a handout entitled Hydroelectric Project Costs for FY 88 (attached).It shows the operations and maintenance staff and costs for the Four Dam Pool Projects and the Eklutna and Snettisham federal projects.It was noted that the O&M cost was approximately the same for all six projects. It does not appear to vary significantly with project capacity. Thus,Bradley Lake can be expected to have roughly the same O&M staff and cost. BUSINESS Spare Transmission Line Towers Dave Eberle asked the committee members for their recommendation on the need for spare transmission line towers.The consensus was that one spare tower,of the largest size required,should be purchased.The legs can be shortened by removing sections for use where a smaller tower is required. VII. VIII. IX. ADDITIONAL ITEMS Dave Eberle asked the committee what design documents the Committee would like to review.After some discussion it was agreed that the Drawing Index,Three-lines,one-lines,all elementary diagrams, substation arrangements,general arrangements,and the cable schedule for the powerhouse and a complete set of transmission line drawings will be distributed as follows ;: CEA -2 sets HVEA =1 set HEA -1 set MEA -1 set ML&P -none Any committee member desiring additional documents should advise APA. NEXT MEETING The next meeting of the full TCC will be held May 5,1988,at 1:30 pm.A combined meeting of the Protective Relaying,SCADA and Governor and Stability Subcommittees will be held May 5,1988,at 9:00 am.Both meeting will be at the APA Anchorage office. ADJOURNMENT The meeting was adjourned at approximately 3:30 pm. Attachments AGENDA MINUTES OF JANUARY 14,1988 MEETING PLAN A COMMUNICATIONS SYSTEM ("OPTION A") PLAN B COMMUNICATIONS SYSTEM ("OPTION B") HYDROELECTRIC PROJECT COSTS FOR FY88. 4587R/CG -6- VI. AGENDA TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY April 14,1988 1:30 PM Alaska Power Authority 701 East Tudor Rd. Anchorage,Alaska Adoption of Prior Meeting Minutes Approval /Modification of Agenda Project Status and Schedule Subcommittee Reports A.SCADA B.Protective Relaying C.Governor and Stability Old Business A.Proposed Homer Operations Center New Business A.Spare Transmission Line Towers 4362R/210R/LS - Attendance: Dave Eberle Oscar Johnson Afzal Khan Don Shira David Burlingame Vance Cordell Bradley Evans Paul Johnson Tom Lovas John Huber Maynard Gross Sam Matthews Tom Small Myles Yerkes John Cooley Ron Krohn John Yale TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES THURSDAY,JANUARY 14,1988 (At the Alaska Power Authority,Anchorage) Alaska Power Authority Alaska Power Authority Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Homer Electric Association Matanuska Electric Association Municipal Light and Power Stone and Webster Engineering Stone and Webster Engineering IT. III. Iv. VI. Adoption of Prior Meeting Minutes The Minutes of November 10,1987,were accepted and stand as written. Approval/Modification of Agenda The agenda (attached)was approved without change. SCADA Subcommittee Report John Yale summarized the Minutes of the November 10,1987,SCADA Subcommittee Meeting. Governor and Stability Subcommittee Report John Yale summarized the Minutes of the January 13,1988,Governor and Stability Subcommittee Meeting.Copies of the Minutes and attachments (attached)were distributed.Several minor corrections of typographical errors were noted.The Minutes will be revised by John Yale and redistributed. Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation The State Division of Telecommunications (DIVCOM)is communicating directly with HEA on path and real estate needs.Tom Small stated that they are discussing alternate microwave paths but,he is not sure of the status of DIVCOM's efforts. It was requested that Mike Ridge of DIVCOM be invited to attend the afternoon SCADA subcommittee meeting where the communication will be discussed in detail. New Business A.Summary of Stability Study Results John Yale summarized the results of the Governor Stability Studies completed by Fuji to date. The studies reinforce the preference for a programmable digital governor.This will allow the time constants to be changed corresponding to the isolated or connected condition,and load.Additional stability studies will be performed based on expected load conditions provided by the utilities.This issue is a continuing item for the Governor and StabilitySubcommittee. The Subcommittee concluded therefore,that system dynamicstabilitystudiesshouldbeperformed.A scope of the neededstudieswillbepreparedbySWECanddistributedtotheTCC members prior to the next meeting. 3912R/191R/CG 1 Dave Eberle noted that system stability studies are not necessarily part of the Bradley Lake Project,but if they aretobedone,they should be set up to accomodate continual updates of the Railbelt system and future studies.It may bepossibletohavetheUniversityofAlaska(U of A)do thestudiesasacontinuationoftheIntertiestudytheyare presently working on. Dave Burlingame stated that both dynamic and transient studies meed to be done.He believes that U of A already has the database and program to do transient studies. The studies will be discussed by the Governor and Stability Subcommittee after the scope of services is prepared. B.Proposéd Homer Operations Center John Yale outlined a proposal by HEA that the SCADA master station presently located in the Bradley Lake Powerhouse Control Room,be moved to an operations center in Homer. Tom Small explained that HEA is looking at Bradley Lake from the viewpoint of the overall Kenai system.Locating the SCADA master terminal in Homer would enable HEA to monitor the project and their transmission system. The arrangement of the SCADA System and the data that will be available to each utility was discussed. Vance Cordell stated that all of the data that CEA gets on its RTU will be available to the other utilities via DECNET. Several concerns were raised regarding the data to be monitored.It was decided to discuss these issues further during the afternoon SCADA subcommittee meeting. Additional Items Discussed. Dave Eberle asked HEA about the status of the contract with Tesoro.Tom Small responded that negotiations were ongoing. Tesoro is starting construction of 4 units,8 MW total.The final outcome will be known mid-February or early March.This information is needed as it will affect the scope of the system studies. Dave Eberle handed out revised project schedules (attached) that were approved by the APA Board in December.The first handout shows a comparison of the Original Schedule,a Revised Schedule created about a year ago,and the current Proposed Schedule to account for the one year APUC delay.The second and third handouts show a breakdown of the new schedule by contract upon the APUC review exemption becoming law by March 15,1988. Tom Small noted that previously HEA's transmission line was required by winter of 1990.He asked if that was still valid. Dave Eberle responded that APA is planning on HEA'stransmissionlinebeingavailablebyOctober1990,so APA can backfeed power to the Project. 3912R/191R/CG 2 VIT. VIIT. IX. HEA asked approximately how much load would be required for the backfeed.Ron Krohn responded with an estimate of three to five megawatts. Dave Burlingame asked if a Relay Subcommittee existed.He was advised that one does exist.However,it was proposed that the protective relaying be discussed in a combined subcommittee meeting with the Governor and Stability Subcommittee. Next Meeting The next meeting of the Governor and Stability and Protective Relaying Subcommittees will be held on April 14,1988,at 9:00 a.m. at the APA offices in Anchorage. The next meeting of the TCC will be on April 14,1988,at 1:30 p.m. at the APA offices in Anchorage. These dates are tentative and will be confirmed later. Adjournment The meeting was adjourned at approximately 11:00 a.m. Attachments Agenda Minutes of January 13,1988,Governor and Stability Subcommittee Meeting Bradley Lake Schedule Comparison Proposed Completion Schedule Bradley Lake Contract Target Dates 3912R/191R/CG .3 AGENDA TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 14,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Adoption of Prior Meeting Minutes II.Approval/Modification of Agenda III.SCADA Subcommittee Report IV.Governor and Stability Subcommittee Report Vv.Old Business Communications -Path study and real estate requirements at Diamond Ridge Substation VI.New Business A.Summary of Stability Study Results B.Proposed Homer Operations Center VII.Adjournment 3603R/CG IECHNILAL CUURDINALING COMM111EE GUVERNUR AND SIABILIIY SUBLUMMLTIEE BRADLEY LAKE HYDRUELELIRIC PROJECI MINUTES WEDNESDAY.JANUARY 13,1988 (At the Alaska Power Authority.Anchor age) Attendance: Dave Eberle Alaska Fower Authority Oscar Johnson -Alaska Fower Authority David Burlingame Chugach Electric Association Bradley Evans Chugach Electric Association Daniel Rogers Chugach Electric Association Myles Yerkes Matanuska Electric Association John Yale Stone and Webster Engineering Ron Krohn Stone and Webster Engineering Ll.rurpwse of the Subcummittee Mr.Yale distributed the aqenda to open the meeting.the pur pose pf the subcommittee 18 to discuss relevant issues regarding the unit governors and their effect on system stability.Also,this subcommittee wtril address relevant issues of system stability in regards to how the project will effect the system and how these effects will be handled.fhis purpose of this particular meeting js to discuss the features of the governor to be provided by Fuji and familiarize subcommittee members with the hardware currently being proposed.fhe agenda for this meeting is listed in attachment 1. II.Overview of Proposed Digital Governor. Mr.Yale distributed a Fuji brochure,attachment 2,which describes the Fuji digital governor.He then distrubuted attachment 3,a block diagram of Fuji's digital governor anda description of Fuji's philosophy regarding reliability and redundancy. the governor is based on Fuji's MICREX-F500 Programable Logic Controller (PLL).It is based on the Multibus II bus.ALL components are on plug in cards mounted in 19”racks.Ibe governor utlizes triplexed main processor units,and duplexed input/output hardware and busses.Critical inputs/outputs such as unit speed,unit trip command,etc.are also triplexed. jhe arrangement being considered for Bradley Lake will integrate the functions of Automatic Voltage Regulator (AVR),governor,and the unit start/stop logic in the PLC.Fuji is currentiy completing work on their prototype for a similar hydroelectric project utilizing this three function integrated arrangment. Fuji has furnished approximately 70 installations utilizing digital governors in steam and hydroelectric applications. However.they are not fully integrated applications. Mr.Yerkes suggested that Stone and Webster obtain an experience list from Fuji on the application of their digital governor. Amoung the information sought should be a list of digital governors in North America,case history on their service records,response times by Fuji to service requests,and mean time between failures. Mr.Eberle stated that Fuji would be testing their prototype of their latest digital governor which would be applicable for Bradley Lake.Ihis prototype 1s being furnished to a Japanese utility.Mr.Eberle offered to send a representative from the subcommittee to witness this test if the committee thought there would be any benefit.After further discussion,it was aqreed that this would not be necessary until the factory testing of the actual Bradiey Lake units being furnished. fhe discussions ted into software programing for the PLt.Lt was stated that programing 15 similar to PLUC's made by Allen-Bradley and obeneral Electric.Concerti was raised that.the Owner /ooer ator entities need to be able to correct software errors without having to depend on Fuji.Buestions were raised relative ta how much traanang would be received trom Fuji.items such as software,trazrnming.and spare parts will be included in a change urder to the contract to Fu). tli.Governor Stability Sudy Results Mr.Evans of Chugach requested that Stone and Webster supply hiin with the assumptions made during the performance of the load tiow and stability studies made in late 1985.Mr.Krohn wali send it directly to Mr.Evans. lsolated operation of the Bradley units was defined as operatiig without a gas turBine connected.fhe normal method of this occuring 15 for the line between Soldotna and University to trip. Since this can occur in a multitude of Locations,there may be a need for Chugach to develop a SCADA siqnal to automatically indicate this condition.lt was suggested that in lieu of a SCADA Signal that is dependent on 4 to 10 second scan update times,it 'might be prudent to detect this change of condition based on the saze of the load error signal.This item will be further addressed bythe SCADA subcommittee on January 14,1988.lt was also noted that while operating in this isolated,isochronous mode,that the Bradley Lake units cannot contrel frequency. Mr.Yale distributed a submittal from Fuji on the qoverning Stability,attachment 4.It illustrates the model for the governor and indicates response characteristics based on standard {EEE parameters for load cases specified in the turbine generator contract.lhe diagrams illustrate the need for a variety of governor settings based on the load condition and on whether or not the unit 15 isolated.ihe easiest way to implement the required variety of governor settings is by use of the digital governor with software change of the settings based on the inputs to the qovernor. fhe cases studied to date were arbitrarily selected by Stone and Webster based on experience.jhe utilities need to advise Stone and Webster of their recommended assumptions for toads.load changes,and acceptable transients for future governing stability runs.Additional items to be addressed by the utilities are the identification and clarification of loads to be carried during i1seclated operation and the point of disconnection to be assumed as this will etfect the load. Mr.Eberte added that the discussions 50 far had addressed only operation ot a single unit under isolated conditions.He indicated that the chances were that both units would be operating rather than just one.Mr.Yale responded that aithough that may be correct,the worst case for stability 15 with only one unit operating.therefore,1f we can make one unit stable, both units will be stable.two unit stability will be examined as part of the studies for the non-1solated condition. fhe discussions shitted anto experience with the terror Lake Frojyect and 1t was pointed out that simpite system actions such as reclosing small loads had devastating etfects on qoverning Stability while operating isolated.Similiar concerns were expressed over the Bradiey lake..Froject operating isolated.the criteria used for the stability studies by Fuji were for S% maximum speed change.It was pointed out that this would eftect the low frequency load shedding scheme.these frequency excursions would cause automatic load shedding to occur,possiblyagrivatingthestabilityproblem. Additional information on irregular loads wil!be required from HEA,especially relative to large loads such as the 2500 HP motors at jlesoro.Information will also be needed on large loads at Seward such as” the ship lift and the coal handling faciltiy. Information needed will be frequency and duration of operation, type of starting equipment.and any agreements that may be abie to fimit the operation during isolated conditions. It was suggested by the Subcommittee that APA should undertake an -Overall system stability study.this is based on past practice with the intertie and previous projects.APA could serve as the interface between the utilities to accomplish the required Program.Mr.Eberle could mot commit APA to such study wathout knowing more about the scope,cost and need for the study.APA did however request Messrs.Krohn and Yale to develop a Scope of Services for such a program for review by the subcommittee.Such program will be in generic terms,not necessarily for performance by Stone and Webster.the Scope of Services should include many contingincies and shauld define end products and required computer stabrlity runs.It was recognizedand recommended that stability runs be performed using the readily available EPRI stability program.fhis program is a good model for transient stability,but is good for only the first and second power swings.lt will not provide results for governing stability. the qroup agreed that use of the proposed digital governor would be acceptable,subject to favorable response from present owners of Fuji equipment on the questions raised. iv.Ad jourment Meeting was adjourned at 11:15 A.M.Next meeting will be sometime near the end of March. Ve Actzaans Kequired Action #1: Stone and Webster tu soliciate antormation from Fiji and utrlity users reqarding digital quvernors suppiied by Fusi. Actiow Hes: Stone and Webster to report on Fuji digital governor prototype demonstration in Japan on March 7,1988. Action #3s Stone and Webster to prepare scope of services for a railbelt system stability study.this is to be distributed for review in advance of the next subcommittee meetina. Action #43 Homer Electric Association and City of Seward to provide data realative to irregular major electric loads as discussed relative to isolated operation.Stone and Webster wil!contact respective parties to clarify the anformation required. Attachments: 1.Aqenda 2.Digital Control System for Hydraulic Power Station -Fuji Electric 3.Governor Block Diagram and Reliability Criteria -Fuji Electric 4.Governor Stability Model and Simulation Results Fuji Electric an AGENDA TECHNICAL COORDINATION COMMITTEE GOVERNOR AND STABILITY SUBCOMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY JANUARY 13,1988 9:00 AM Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Purpose of the Subcommittee II.Overview of Proposed Digital Governor A.Arrangement B.Hardware C.Software D.Advantages III.Governor Stability Study Results A.Results to Date B.Information needed from Utilities for further studies IV.Adjournment 3603R/CG Ful SBUSErieliG Digital Control System for Hydraulic Power Station New Technologies for Hydraulic Power Plant Applications Recently,a programmable controller (PC),a digital control device incorporating 3 micro-processor,has been put in practical use for broad applications,rather than using con- ventional electro-magnetic type control devices,in order to provide higher reliability and simple maintenance of hydraulic power plant systems. The programmable controller is capable of high speed transmission of large amounts of data through a dataway as well as multi-function processing and high speed conputation due to the rapid technical progress in the field of PC's coupled with developments of new peripheral devices such as a CRT display. The MICREX-F500 having such features is designed as a total digital system for hydraulic power plant systems;and is being used not only in conventional control but also for hydraulic turbine governors (hereinafter called "'governor''),automatic voltage regulators (hereinafter called AVR). This programmabie controller is highly efficient,economical and reliable. Advantages of MICREX-F500 (1)Adoption of unit type hardware and software for added functions has resulted in a compact device embodying enhanced cost-performance. (2)1/O units can be installed in various places where data are concentrated so that data can be collected by using a simpie cabie route. (3)The MICREX-F500 can be used not only for a newly installed hydraulic power piants,it can also be used for replacement of existing control systems in such plants. In addition,it can be used in combination with a sequence controller,exciting device or governor. (4)With incorporation of an operation panel,full scaie man-machine interface functions can be accomplished. (5)Use of intelligent Al cards eliminates the necessity of transducers for external analog input/output interface. Functions of Digital Controller for Hydraulic Power Plant Table 1 shows the major functions of the digital controller. Fig.2 shows the functions of the digital AVR,and Table 3 shows the functions of the digital governor. Table 1 Functions of Digital Controller Function Typical example (1)Sequencing (a)Startup and stopfunction(b)Emergency shutdowns 1) :lc)Normal shutdown (d)Automatic switching of house power supply systemle)Automatic reciosing(t)Aux.machine contro! ta)Automatic voltage reguistor contro! (b)Governor speed control (ce)6SF,65P control +Automatic power contro! °Automatic frequency control (d)9OR contro! °Automatic VAR control «Automatic power factor control (e)77 control »Automatic headwater level control +Automatic flow rate contro! (f)High efficiency contro!«2)(g)Various program operation (h)Joint operation (a)Incomplete start/stop sequence (b)Main machine status conditions (c)Aux.machine status conditions (2)Control function (3)Sequence monitoring function (4)Remote {a)Control signal receivingterminal(b)Nurmericat setting velue receivingunit(ce)Supervision signal transmissionfunction(cd)Measuring signal transmission Remarks °1)Used together with magnetic relay emergency shutdown circuit.°2)lenpuise turbine,Kapian turbine Fig.1 Total Digital Control System Block DiagramPeswewpemeevem=me mee ee wm ef me Conve 7 > nme Bd Cowen én FhCo) aweTET LY bel Gudpap|YO wm re.. ' ! Conve .cm |ate lee ee | Table 2 Functions of Digital AVR Table 3 Functions of Digital Governor Function Contents Function Contents Cross current compensation Prevention of VAR current trom flowing into each units when 2 or more generators are in parallel operation Field current limiting Generator fieid current limit in brushless exciting system Minor control loop with a feedback signal of the field current Time constant compensation in brushiess exciting system Frequency compensation Synchronizing signal compensation against speed rise at load rejection Smooth voitage build-up Voltage overshoot contro!at selection from field flashing to AVR operation Reactive power Leeding Prevention of stator core local overhest restriction Lagging Prevention of roror coil overheat Characteristics Dead band:0.02%¢1) Dest time:Less than 0.25 sec «1) Range of adjustments Speed:90 to 108% Permanent speed droop:0 to 10% Momentary speed droop:O to 50% Time constant of damping:0 to 15 sec Basic caiculation PID operation (with 65F and 65P functions) Wicket geste opening control Wicket gate constant opening operation(77) Water level control Upper reservoir constant water level operation Output controt APC,AFC Power output stable control Load distribution operation during paraliel operation of 2 or more turbines Generator AC current restriction Prevention of stator coil overheat Frequency drop compensation Over-excitation compensation (high voltage sync.oniy)of main trans- former in low frequency Automatic reactive power or power factor regulation APfR,AOR (OQ =a +bp) Line charge Line charge PSS OP detection system Manual voitage reguiation ACR system (Detection:Fieid current) Automatic follow-up control Automatic follow-up of manual signal Automatic voltage balancing Function of automatic synchronizing device (#60) Fig.2 Digital AVR Block Disgram0 een ee eeees we eepeen menses 6 Oa Ave Oowe- wen {-ingufovigatwant Lumtng)+Over encase ifHigh efficiency contro! Optimum runner vane opening (Kapan turbine,Bulb turbine) Selecting the number of needles used (impuise turbine) Automatic sowed regulating Function of automatic synchronizingdevice(215) Automatic followup control Follow-up to 65F to 77 during water regulating operation (77) Over power restriction Restriction of over-power Speed droop operation Comouting speed drop Speed relay 13,14,14L 2) Remarks °1)including mechanical control unit*2)12 is instatied separately Fig.3 Digital Govenor Block Diagramtee«eee meee cue ee mee ee e+e Onprtes guwarner Oever.|+Frommer (SSGwn°Wetet ge eperwng+Ettecevecovercane»Brequency caneOars hen +Wenet ge eparwng Orwe unt newVowvtoeeiLereteng|+Waenet gre COmre ©tegagl eriter ing+Quiet mantenng+Sart cregreesiJ Fuji Electric Co.Ltd. 12-1 Yurakucho 1-chome.Chiyoda-ku.Tokyo.100 Japan Phone Tokyo 211-7111TelexJ22331FUJIELEA or FUJIELEB 2-2 High Reliability Design (1)Basic Concept (2) Two basic approaches for the improvement of the reliability of control equipment are as follows.- 1)To build up the faultless system (prevention of failure). 2)To prevent the effect of failure to the whole system (minimizing "the effect of failure). And our concepts of the redundancy are mentioned below. LD A system which is capable of self-diagnosis should be duplexed. 2)A system which is difficult of self-diagnosis should be triplexed. 3)A system which is difficult to be aul tiplex should be not concentrated. D-EHG system configuration The D-EHG system is built with the following configuration: 1)Main Processing Unit (MPU):(Fig 2-1-1) Be triplexed,because it is the most important part of the system, and the self-diagnosis for computed results is impossible.. 2)Control power source supply:(Fig 2-1-1) Be duplexed to assure the control system,even if one of the lines is down. 3)Input/output unit:(Fig 2-1-1) 1/0 unit is duplexed commonly to 3MPUs,because self-diagnosis is possible. AO (HRAO)(Fig 2-2-1,Fig 2-2-2,Fig 2-2-3) AN 22 4 08 .--- @) 6) khen a failure is detected in the AQ card,it is turned off and Simultaneously the another AO card on standby is on. DO (Fig 2-2-4) Same as AQ. DI_(Fig 2-2-5) Same as AO. But some important i/os mentioned below are triplexed and directly connected to MPUs. Triplexed PI -Input of turbine rotation detection(Fig 2-2-6) Triplexed DI (Fig 2-2-7) -Input of 526 -Input of turbine trip -Input of PT fuse blow +Input of turbine starting system Triplexed DO (Fig 2-2-8) -Output of turbine starting system Triplexed AI -Input of control valve opening detection (Fig 2-2-9) -Input of generator output detection (Fig 2-2-10) -Input of HT ITM(Interface Terminal Module):(Fig 2-1-1,Fig 2-1-2) Be simplex for each i/o signal,because of duplexed I/0. Input/output serial Link (T-link):(Fig 2-1-1) Be triplexed because the MPU is triplexed. MPU serial link (P-link):(Fig 2-1-1) Be duplexed. Omu tras Jeu cA SHELF ate on - oe Cou >-7”Todi eet ves OO errraaasee T-LINM af-9 ato? -s 9 -.- t/o-l SHELF - ford SHELF jcsa][tes ](tes |[rs pow}fcsu][ms]ins |(ns ot watt outs want?bute w 28 co >Cf -)Rectectco)ccfeatealcs|cal ma fcolce]ce)cs cates]es]cs crertorteeen 2rmaot[enao|[rao]frnaoy [ov |[or |{Oe F |oO»rao}[rao][enao]ferro][or ff ov J [Oo ||0.(ron tinoF 1.00}Urs pote se nee rT :De }fus fifi i Alaa |.]Al li i]oon ili]QUIECA POOR SFPLE FoR 170 {eke!)tld i |J |||!|(Fon in oF On vow]Ps ad v t ° ok ereee: \\\||FORA OTL FON ATLAS An es [ coy wm uvFoncamateeor|ray {Ps }Ole w ee ew enw ele JR ee OL HJ ele LL RR tm em eRe Km me 7 wee enna cl es J ¢oCmole 170 >ad Ge °fete twroeane unctnt anton 00s MAPOWAAL ACETAL AA|.¢oa ood LS ddae 1 Scns see cont ett amAP,COCR POUT)BFLET PORCINE MA<quica >A : ;1E AME 2 TT JAN,10,0067 POWER SOURCES ANE NEVISED =Da La 0-E€HG CANOS =ble deren - ll Fujl Electric Co.ltd jz 4 ae Dec.15.07 ofalo =|AND POWER SOURCE CONSTRUCTION [ )Revised Mar.19,'87 an _. 0696S Cd Outline The stability of turbine governor for Alaska Power Authority,Bradley Lake Hydroelectric Project was analyzed using a simulator.(SHYTAP) As the result,the setting of governor constant in Table 1 was determined appropriate,as follows. Table 1 Governor Constant -_-a +”a a oo aass Constant Name . Set Value eeeeeee Power Output 20%70%90% Proportional gain Kp "168 0.7 °0.9 Integral time constant Ti 10.0 20.0 20.0 Differential time constant °Td 1.1 1.1 1.1 Droop bp 0.03 Jiacsshionantiarantleasel Condition for Calculation 2.1 Governor function is shown in Fig.1,block diagram.DEFLECTOR /NEEDLECURVE +<7 DEFLECTORaE1100}sas 5 776!Ts922.0 65F,+ff +.Io 7]NEEDLE NOI+J -h O sn +f Ol Tsx =60.0 +Qe :_NEEDLE NO2 NO6 Q03 65P hacen =<_- CALCULATION OF F-NEEDLE NQ2 NO6 TOTAL'OPENING FOR NEEDLE FIGI,BLOCKDIAGRAM FOR GOVERNOR -'l- blSW. E, C.. ! BRADLEY LAKE P/Y5 CASE R-4-2-sase| 7 -_ > ."=a : 3LY v.esw &; oe3 22"E12ya ry="Awo ™ =-_= = S-oO.=ASSLoeS , an oo "” soo ud e "ts an = x "7 ;j;= Y| [tt ': ;) to] x Peial ii;73|e ™ [oo Day =m .3 ---= :!! ann +.$Pie te da® soe w uo cod t mw :ii ' it ::i Nw (1jile |BSe so: 0 LB en i| ' :1 %= ;'. =aq food zoe Jtefiilg|gaqe | r!o8 PS TBS ; i! Ags +24 non e. - ! 3! oor moe , , us ,\ tte OL *AN\Ps o=22 i re) i HPa: 'a e Wg : ° s ro e mo 5 :: ' Bee} i ' : i) ' bi e N msae:: t ar +S ' . ™N rome ' a-;+' [ ] Catered Pw m_ ral '== . oe aera L Ree se fE S = WOOT TTri irititrassss=4--_ nn ' = -m---enna } om ON emer meee ole cane TID' ” 'i . | (41 NS : ! Mu I (41 Ids a3&3a¢2°2 od jesand | it L_= | Wi THe g =} Q °o ° m : :S332¢2S co ' 3 tooo § m0g 8s2&8¢&&§8 pidge'pee (%} INS 88e3a33532 Oe*¢§ 2 te cememmem erates emcee:26 1 eae omens tee ems fee ee eo mee ne oe oe ee eee (%){7%}(2)8&60 |60 60 70}70 70. 60]60)3 Pg 52.6% $0)80 1970 |SO |rE TS TE TESTS TS SE ST ES FT 40]401360]40) 30 |301350]30 204 20340]20] 10]10 4330;10 fit nh2ni_n v v v ¥T T v v v v v 0 S50 100 150 200 250 300 350 400 450 500 ssa 6 650time(ofc) -----_-PC PCE=59850 KH CO2=eu0nee THM sensesSeeceee UE tt =358.32 4 Q =24.87 43/5 --------UI N =300.0 RPM ag Fn _- Alaska Power Authority BRADLEY LAKE SCHEDULE COMPARISON 1987 1988 1989 1990 1001 J |I ||i ]|I }T T T 1 ORIGINAL SCHEDULE UNIT 1 BID OPEN FILL FILL |UNIT 2 \ 0oc spa NTP RESEAVIOR TUNNEL om 47 ot 7/16 6/4 10/1 92/1 971 2¢+Mo |2-22sto|wo REVISED SCHEOULE (3/13/87) 'SSUE FILL FILL UNIT 1 UNIT 2 TUNNEL O/L O”L810OPEN Doc BIOS NTP RESERVIOR 6/16 7/16 O/1 ron ant 7)0/1¥-7 k a MN |31 Mo Ls L2-| PROPOSED SCHEDULE ISSUE CALL UNIT 4BIoFOROPENFILLFALL UNIT 2 poc BIDS =B1I08 NTP RESERVIOR TUNNEL \on ove 3/16 8/16 779 +ast THN ouPos $2 Mo |2 | 12/67 Bradley Lake Hydroelectric Project PROPOSED COMPLETION SCHEDULE 1968 1969 1890 19901 beeue Bid Notice to Proceed ema \FtBidDocOpening(NTP)eoervols Ht Tunnel CompCONSTRUCTIONerase?6/16 741 ms |ant ont - 5 zy 7 GENERAL CiviL t qLK.[= wTe 3716 6/16 e716 CAMP &CATERING Lele,i : | Inetalt Start NIP Embedded Paris Testing ert O71 10/16 vite we POWERHOUSE bie Construction | wre 3/16 6/1 @71 T/L CLEARING Als J NYP ost sa Ort tJ } T/L CONSTAUCTION uty Procurement J Conetruction J WTP $2716 see ast+7 *>D]D_]NUKA/MIODLE FORK DIVERSIONS ose| nte at ort vere ¥v y ripSITEREHABILITATIONBhipuy Embedded Ship ait Chi”Parte Turbine/Generator 91196 3/16 os16PROCUREMENT _ v 7 . }Febricate tnctell and Teet TURBINE/QENERATOR eer I 4/0 O78 va inetall and Test SCADA Bid |-|{] taser eeoge>e >cS 2AlaskaPowerAuthority9e&K Pd 2&oe AQBRADLEYLAKE@g92A esRYc/txv/a ¢$NTRACT TA C)Q 2»9%ScoCcRGETDATESsdoge e & GENERAL CIVIL o/ase7 |6/16/88)7/1/88 N/A |374/01 |Osts01 4 CAMP &CATERING 3/16/88 |6/16/88]6/16/88 |N/A NA 9/1/01 TURBINE GENERATOR N/A NIA |9716780 |oooee ayasos |ortvos0/16/89 SCADA 4/1768 |6/16/68|7/15/88 |1989 |1/1/09 |978/01 POWERHOUSE 6/1/86 |0/1/88 |10/16/88]NVA 1/1/01 |os1so1 T/L CLEARING 3/16/88 |6/1/88 |6/1/88 NUA NIA 1/1/89 T/L CONSTRUCTION 6/1see |7/1/68 |e/1ve8 |1080 nNva |ostse0 NUKA/MID FORK DIVERSION |so;46799/3/1/00 |4/1/00 N/A N/A |10/1/00 CONSTRUCTION SITE REHABILITATION 2/1/01 |4/9/09 |671701 NIA NIA |4409/01 12/87 CASE 20021 )HeycAaa-soe eb Lent ot Soba E ST ASSETSE SPSS ETT cp "8S Speer sranase TCU TIT STE TESTER OF Fage RESERVES TS $sorwfopalofoI] a ene Mate -f--te-f en .|--_-_- -_--a ae ee ee ee ied lial Cc ee ee ee ee ee ee ee CG ee ee eee ee es el ---a es ee er:oa =-==--.of):6.2S ee ne ee wee 5 8 ee amas ame e encmes 5)oe ree a en -----[F--=-=KRe--meer mr psy reper TTT INeeeefeee|__|-- ee :-lease 20023 fo 7 -h -wee ,7 Se mre me me eee -----_-'a NNN ae Nt ey ---i-aSPeewepceneotters©SEE tne tee sterenen eames oT Sn SN Co a ee _S 7 rn nee a d Sree errs OTT Sas ts c=__Sr $ TS st termes eres'oo "NY coe ae tsa a”sa Ce Ad co CN gb d§00 LOUTP EE oa aS 0 Oore Norme Jo Yo d OA O i j oreen |==Fuji Electric Co,Ltd |, Ets,i T ”¥a ¢t 0 0 'Oe CASE Aol rYJ seq |e CASE Jor fa --4---of case 20222 --|}- |case 207 30 - ey eens TraaLsaeo CASE 20223 .F !OS art --4 ..ti.:. :1 :;os orem Teh bc OX ocd ;on ee S Seed pl beeeiiieeees ae ee OO 1020 TSO | Oete teme fa}ff,LOAD g 9|a Fuji Electric Co,Ltd |3 10%!/ fag 2 r 1 o Oo Ft oe Jease we20 SOD PT SD te ;shoo DONT CEE cee]. soe rt)Oc coo Ne worl cero Soo :_- 7 NS SS i -=,ot ee SS 2 ------}------|Jesse On CASE 70922 --f---|case 20 032g.ssos2es 68 a a es e@ Lr eon ww 6 ;i,ens ra et et er ee ee ee ee-_--es ree eres we ee ene o-]-=.PiepkA.VYRToati Ss ee CORSES SEEEEE:(EL SENNN nn ae a ---oe >.lodtinee Gemeeeienesto _---ee..__!_a __----4 le SS -somes a eenes pone ss 8 3 ©8 ©©©&ws ©= IT)IES or 228.0 ay 0a)_|[50 - tT Fujl Electric Co,Ltd |2 70 Yo LOAD i boy FAY s Li JCASE POI 7s Re Fe it XS - fa CASE 70322 ee Ce ee ee ee ee eee ee ee ee ee ee a a a a .S 8 2a _3 t 3s a ero eee ey ee eee ===foe eeeeee re er pala |-Nae Dn LPT ease ror23 ae - - - - * wee .-5h io =,- -. _|__Nn ee Pee Jee yg SS==]5 x oS2EE :+ Hae ee < ee eee Ne pee bee ee =TTT |a eee ee Xen Se -se = DE Or2500 ee aan 00 -LS -| Date Mere 70 %LOAD 'Y"|Fuji Electric Co,Ltd.|2 Lip be iHE rY T 8 Ta OC T o oO i!Oe .af CASE VoO24 co ceraeieceees ce gcae wep ees Gunete wus heat -"|CASE Yoo ta .-_|_._.AH B}casé 90023 _case GoOR.. _ .: . :.™N Pe ee te ee erie ::4 ::N\N UPL.a ere san op |--' oe 8 a «Ld oe @ oele ee ee ee ee ee ee ee - se "2 XL oT2280.10.0 [3-0 90%LOAD Ei 2,i|a Fuji Electric Co.Ltd.Ticerr J B [aA ¢q 0 Oo Ff Oe O -wees Nease for at ©-time we lee wet eee eee See __-. :N\j a)Se "E :NN i_=, - 7 -i] |ease toni _--|--AY |ecleasefot 2a ae I tease tor 32 ” : es ee ,mo -oe meee me a von ™- _ Y -wee nronee ceeee Penn ia OO 7 Li.7 wo |--- f ---a ne SO So Se ee LL eeeeee ee me hmcas@_Qor23 Leasagen3aaCeeaees=Ftote.tee .-NN.-|---ry r)7 Nn EIS pe 100 =roo _ Oeste Mere ] re)Z OAD -Fuji Electric Co,Ltd |#90%nay.Pen.»Fig 8 i a 'az C¢'o Oo Oe T rs |G t H ae 7 7" Talfp ye [ig a /a.uw 6 (agaf - c 9 on: : Ww | (é] Oo 4 < 7 ooo ee ee;ee eee - ra) >»7 \ ba w/ A gg c SEO z =| . é o _-4 N > hed g A > N rf J 7 " w 5 \ " ee ao OPERATIONS CENTER (cou-| l | | I ; I | 1 | l | | | | | 1 ! J I ! | I { \ '\ se AMO 10G HOMER HEA/AEGC&T | \ N Lea OISPATCH RT}rtu||Rtu| PLAN A COMMUNICATIONSSYSTEM FIGURE 3-2 Tro EREB01PADee -O-os-”cleipycsetildtinytN240504onoNe009HGRA.-””O-MrWiimernhstss*penveatsdA7 -|Ty TRIP / 7.TEA N/DISPATCH \ /\ \ \ !: .TO ANCHORAGE =Fan/7 7\/" - N 4 ee 'N f RTU Sy 7 /-”1 ---I SOLDOTNA ¢/ / 7 / / / 7 HEA/AEGAT \/ /OPERATIONS \7/CENTER \/x //\/ /-TRANSFER| !"BRADLEY JUNCTION HOMER |||/N\FNord Yo -*\- ,"eK oN -*'NTIt-X.--_____|_\|Swe }|il /= L |||OTAMONO|7 ,|R1IOGE {7?\1 f \a i11i4,1!Lo.AT |vo 'S 1./im 4 BRAOLEY \|/)|LAKE \ LN.|=)\Seeceeeeecccccescceeeeee rey}AS'\ ---------woman nnn ne q------1 --¢-fara]/\INN /\i\N /'\/VX / .hv SvSA/Ley /\\ [ato][ar][ar] PLAN B COMMUNICATIONS SYSTEM | FIGURE 3-6 p42.275 HYDROELECTRIC PROJECT COSTS FOR FY88 The following costs were budgeted by the Four Dam Pool for FY88: 379,882 114,743 1,334,044 6,373,792 500,000 50,000 8,752,461 984,546 822,909 1,082,796 945,152 Power Authority cost to manage the operation of and comply with licenses and permits. Environmental studies required by FERC license Insurance Debt Service Repair and Replacement annual contribution Project Management Committee expenses Operation and Maintenance Solomon Gulch Swan Lake Terror Lake Tyee Lake 3,835,403 $12,587,864 A74.G110 SOLOMON GULCH DISPATCHING ENTITY:Copper Valley Electric Assoc. MAINTENANCE ENTITY:Copper Valley Electric Association PERSONNEL FY88 Chief Plant Op .88,994 Plant Op (5)402,235 Lineman °80,447 571,676 Transportation 4,800 Training 5,000 PMC and Technical Standards Committe 12,000 Liability Insurance 45,120 epair/fuel 6,850 Transmission expenses 77,200 Materials 36,000 Phone=-SCADA 47,500 Contracts 178,400 412,870 TOTAL $984,546 Q1.W40 DISPATCHING ENTITY: MAINTENANCE ENTITY: PERSONNEL Ops Foreman Mech/Electrician Mech/Technician - Op/Dispatch &SCADA (3.7) Temporaries Meter Relay Control Line Crew Contractual field sve eng. Travel Air transport Training Equipment Fuel Heating oil,waste disposal Materials TOTAL SWAN LAKE Ketchikan Public Utilities Ketchikan Public Utilities FY88 88,900 77,737 77,738 255,944 14,000 21,000 70,000 605,319 20,000 24,800 24,000 9,500 14,000 11,350 8,750 105,190 217,590 $822,909 Al.G33 TERROR LAKE DISPATCHING ENTITY:Kodiak Electric Association MAINTENANCE ENTITY:Kodiak Electric Association PERSONNEL FY88 Mech-op TL (3)213,511 Chief Mech/Op TL 81,678 Dispatcher (4)-276,140 Dispatcher Relief 38,432 Kodiak Mechanic (TL help)35,585 T &D Electrician-Lineman 71,170 716,516 Travel 54,900 Training 7,353 Fuel 6,600 isc.105,427 Materials ;134,500 Contracts 57,500 366,280 TOTAL $1,082,796 TYEE LAKE A37.G72 DISPATCHING ENTITY:Thomas Bay Power Authority MAINTENANCE ENTITY:Thomas Bay Power Authority PERSONNEL FY88 Manager 74,900 Operator (3)234,250 Lead Dispatcher 69,590 Dispatcher (2)126,409 Dispatcher Trainee 57,121 Casual/Part Time 11,165 573,435 Gen.admin,travel,insurance 159,702 Air service 33,410 Clearing 40,000 Fuel 10,000 Supplies/Materials 82,445 Contracts 46,160 371,717 TOTAL $945,152 h1l.o042 EKLUTNA DISPATCHING ENTITY:Alaska Power Administration* MAINTENANCE ENTITY:Alaska Power Administration* PERSONNEL FY88 Area Power Manager (elec eng)68,300 Electronics Technician 54,486 Admin.Tech.-27,644 Powerplant Op (on site 8-5)26.21/hr Lineman (maint)General Foreman 26.92/hr. (to be contracted out this Fall) Maintenanceman (vacant) Hydro Mechanic/Foreman 25.45/hr. Electrician/Relief Op 28.00/hr. Heavy Equip.Mech/Op Foreman 26.43/hr. "569,000 Travel 28,000 ransportation 25,000 Utilities 15,000 Other Services 50,000 Materials/Supplies 60,000 Equipment 215,000 393,000 $962,000 NOTE:*With proposed Municipality of Anchorage acquisition, 2 FTE for AML&P Maintenance,dispatch by CEA. H44.086 SNETTISHAM DISPATCHING ENTITY:Alaska Power Administration (*AEL&P) MAINTENANCE ENTITY:Alaska Power Administration PERSONNEL FY88 Project Supervisor (at substation)68,300 (*Manager and 1 Clerk) Electronics Technician-50,069 (at substation) Lineman/Electrician/Op 25.48/hr. (at substation) Elec/Op (2 on-site FT,overlap 24.00/hr. 3 days at each change) Elec/Foreman 23.62/hr. Hydro/Mech/Op/Gen Foreman 28.38/hr. Mech/Op/Eng/Equip Powerhouse Op 23.62/hr. Summer temp laborer (14.08/hr)&lineman not budgeted Electrician trainee (17.70/hr)not budgeted 492,000 Travel 80,000 Transportation . 35,000 Utilities 8,000 Printing 1,000 Other Services 103,000 Materials/Supplies 151,000 Equipment 454,000 832,000 TOTAL $1,324,000 NOTE:*With Alaska Power Authority acquisition. STONE &WEBSTER ENGINEERING CORPORATION SEBS GREENWOOD PLAZA BOULEVARDAENGLEWOOD,COLORADO 80111-2113 ane AREGSOHSENER TOA F8.O.BOE 2408,@enven.COLeRs0O 20217-5406"ee wae eo TRLEPUONE:996-741-7780eovrTron GugaRy mts,NZ.@.y.TWEE:610-028-9108Souaree.U.TREN:48-4008 wew vosoaL.se Qce TEREE:sweees MICHLAND.WA waeningefon,0.¢. Me.D.R.Eberie August 19,1988 Project Manager Alaska Power Authority J.0.No.15800.49 701 East Tudor Rd.WP 19A Anchorage,AK 99503 SWEC/APA/2288 PROPOSALS FOR GOVERNOR ALTERNATIVES CONTRACT NO.2890033 HYDRAULIC TURBINE/GENERATOR UNITS AND APPURTENANCES BRADLEY LAKE HYDROELECTRIC PROJECT. Enclosed ig a copy of the Fuji August 17,1988 FAX,FUST/SWEC/229-F and FAX August 19,1988 FUJT/SWEC/231-F.The Fuji proposal for alternate governor alternatives is described below: The costs acscociated with the Fuji Digital Covernor per Contract Change No. Ge: SUBSCHEDULE C Item Unit Extended No.Description Quantity Price Amount 3 Manufacture,Purnish 2 ea.9501 ,466.50 $1,002,933 and Deliver Electric- hydraulic Governors and Associated equipment end accessories 6 Delete Gov.Pony 2 ea.'$(3,735.00) $€7,470.00) Pump &Accessories (Decrease) 9(a)Delete {ntercon-Lump Sus $xnxx $€3,460.00) necting Piping betveen (Decrease) Gov.Systems of Unit 162 (Dp) AdG Dlind plate for 2 sets $140.00 $280.00 gov.piping (Increase) 720 72D *ON Canad ESTISNols FM 3ST PRET FA Mr.D.R.Eberle 2 August 19,1988 11 Furnish Gov.2 ea.$8,685.00 $17,370.00 Electronic Cabinet (Increase) 12 Furniah pressure Lump Sum $xxx $15,140.00 reducing valve, Piping &access for Generator Brake System TOTAL:$1 ,026,793.00 I€we elect to change to Fuji analogue governor system,the contract pricewouldremainunchanged,but delivery of the governor would be delayed for Unit 1 from Sep-17-90 to Mar-17-90 and Unit 2 from Nov-02-89 to May-02-90. If we elect to change to the Woodward digital "501 control”systes,the contract price would increase from $1,024,793 to $1,103,000.Delivery of the governor would be delayed for Unit 1 from Sep-17-89 to Oct-17-89 and Unit 2 from Nov-02-89 to Dec-02-89. Fuji proposes to fully pass the Contract requirements and «associated guarantees and warranties on to Woodward should the Power Authority select the Woodward governor alternative.However,Woodward has requested some deviations from the apecification requirement. 1.No isolated test jacks are to be provided.The self-diagnestic capability of the "501 Control”should identify the oature of any computer failure. 2.Actuator Lock:The standard governor lock-up will be used on the deflector relay valve system.While tocked,it may still be operated via the Deflector Limit Control. 3.Speed Droop Changer:The governor will be equipped with SpeedRegulation,adjustable from (0-10)with indicator behing the access door in the cubicle. 6.Sump Tank:A leakage oil tank and it's auxiliaries will not be provided as part of the Woodward proposal. 5.Valves and Piping:The only piping and valve being provided isbetweenthepressuretank,pumps and the actuator cabinet.NootherinterconnectingpipingisbeingprovidedbyWoodward. 6.Leak Test:The sump tank is normally vented and pressurizing thisareawouldbeextremelydifficulttodo;therefore,the sum tankwillbeinspectedforoilleaksatambienttemperature. £0 228 *ON eS wad Ear2SNOuS vast 6861 -6e Mr.D.R.Eberle 3 August 19,1988 7.Presgyre Test:All individual components are pressure tested at150%of normal pressure.If it is desired that the system be retested in the field,we wish to draw your attention to the following: a.All pressure safeties would have to be readjusted. b.Pressure switches would have to be bypassed. c.The present governor oi]pump might have to be increased in Capacity or a special pump installed to perform the tes:. 8.Woodward recommends that a Woodward Representative be present, when this test is performed,to assict in recalibrating the pracsure devices. Originally Woodward wished to limit the equipment temperature rating between O°C and SO°C.Woodward hag indicated verbally that they did not have the actusl epecification requirements at the tise they listed this concern.Woodward now advisec that they can meet the specified O°C and70°C requirement. In the event thet the Technical Coordination Committee (TCC)does wish to adopt the Woodward '501 Control"Digital Covernor,we would recommend that a coordination meeting with Fuji and Woodward be scheduled at cur Denver offices early in September.This meeting would enable our engineers to underatand what governor components are being supplied by Woodward andFuji.We also need to discuss a number of technical and administrative matters. I will continue to keep you verbally informed of any further communications with Fuji on this matter.Should you wish to discuss the above,please call. N.A.Bishop Deputy Project Manager NAB/CH Enclosures POS 220 °ON wrBI gssRoLs - SB9T ga/61-ba 9/32/98 Steve Cowper.Governor N TCs Weert Uta ark,ah Alaska Power Authority State of Alaska December 8,1988 Mr.David Burlingame Chugach Electric Association P.O.Box 196300 Anchorage,Alaska 99519-6300 Subject:Bradley Lake Hydroelectric ProjectTechnicalCoordinationCommitteeMeeting -December 15,1988 Dear Mr.Burlingame: The next meeting of the Technical Coordination Committee will be held on December 15,1988 beginning at 9:00 a.m.at Chugach Electric Associ- ation.Attached is the proposed agenda for the meeting.No subcommit- tee meetings are presently planned. The following support materials are also provided for your review in advance of subject meeting: -TCC Meeting Minutes,August 22,1988. -TCC Meeting Minutes,October 12,1988. Stone &Webster Letter of October 28,1988 -Future Electric Service to Bear Cove. Alaska Power Authority Letter of November 7,1988 -Wood Pole Structures at Bradley Junction. .Utility Letters Designating TCC Representatives. MEA Memorandum of October 31,1988 -AGE&T/HEA Issues of Concerns.aw>WNe°eAs agreed during the last meeting,this notice is being sent only to theprimarydesignatedTCCmemberofeachutility.TCC members are responsible for internal notification and dissemination of these materials within their respective utility. I you should have any questions regarding the above information,please give me a call. 0 VM L David R.Eberle RECEIVED BY Project Manager DEC 12 1968 DRE:t14j ENGINEERINGmeecm0ORATTAT Enclosures as stated =PO.Box AM Juneau,Alaska 998114 (907)465-3575"KX,PO Box 190869 704 EastTudor Road ==Anchorage.Alaska 99519-0869 (907)564-7877 4474/922(2) TCC Information Packet for Scheduled Meeting of December 15,1988 Distribution List Mr.Steve Haagenson Golden Valley Electric Association P.O.Box 1249 Fairbanks,Alaska 99707 Mr.David Burlingame Chugach Electric Association P.O.Box 196300 Anchorage,Alaska 99519-6300 Mr.Myles Yerkes Matanuska Electric Association P.O.Box 2929 Palmer,Alaska 99645 Mr.Sam Matthews Homer Electric Association P.O.Box 429 Homer,Alaska 99603 Mr.John Cooley Municipal Light and Power Municipality of Anchorage 1200 East First Avenue Anchorage,Alaska 99501 Mr.Jack Anderson City of Seward P.O.Box 167 Seward,Alaska 99664 4474/922(1) AGENDA Technical Coordination Committee Meeting Bradley Lake Hydroelectric Project December 15,1988 9:00 A.M. At Chugach Electric Association 5601 Minnesota Drive Anchorage,Alaska I.Adoption of Prior Meeting Minutes A.August 22,1988 TCC Meeting B.October 12,1988 TCC Meeting II.Approval/Modification of Agenda III.Old Business A.Status Report -SCADA Proposals B.Stability Studies 1.SEI -Final Results 2.APA Independent Assessment C.Bradley Junction to Fritz Creek Transmission Line D.Reduced Generation Load Cases IV.New Business A.Relay Installation -Payment Arrangements B Wood Pole Installation at Bradley Junction C.Bear Cove Electric Service D Issues related to Project Operations vs.Power Sales/Services Agreements V.Adjournment 4474/Agenda/922 TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES Monday,August 22,1988(At the Alaska Power Authority) ATTENDANCE Dave Eberle Don Shira David Burlingame Bradley Evans Steven Haagenson Maynard Gross Sam Matthews Tom Small Myles Yerkes John Cooley Larry Hembree Ron Krohn John Yale 4439/919(1) Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association/Alaska Energy Generation &Transmission Homer Electric Association Matanuska Electric Association Municipal Light and Power Municipal Light and Power Stone &Webster Engineering Stone &Webster Engineering I.ADOPTION OF PRIOR MEETING MINUTES The Minutes of the July 12,1988,TCC meeting were approved and stand as written. The following changes were made to the Minutes of the July 12,1988 Relaying Subcommittee Meeting: Page 1,first paragraph,fifth line;"low impedance faults"should read "high impedance faults". Page 1,first paragraph;the last two sentences are deleted. Page 2,the sentence at the top is deleted. Page 3,action item for HEA &CEA;delete the first action item. The Minutes of the July 13,1988 Stability Subcommittee Meeting were approved and stand as written. The following change was made to the Minutes of the August 3,1988 Stability Subcommittee Meeting: Page 1,fourth paragraph;add the following sen- tence."Further information to be provided follow- ing final results of the SEI Study." II.APPROVAL/MODIFICATION OF AGENDA The Agenda (attached)was approved without change. 4439/919(2) III.OLD BUSINESS A.Protective Relaying Changes CEA and HEA had requested that the electro-mechanical trans- mission line back-up relays be replaced with a dual-primary Schweitzer 121/121G package (see July 12,1988 Minutes ofRelayingSubcommitteeMeeting).Dave Eberle stated the transmission lines being protected are primarily HEA's and CEA's,and that APA does not have a strong preference,thus the decision is up to the utilities.The Committee recommend- ed that the relaying be changed to the Schweitzer package. APA will make the change accordingly. B.SCADA RFTP Comments SWEC responses to the comments received prior to the final draft of the RFTP were previously distributed.The additional comments received from GVEA and HEA will be responded to andincorporatedinthenextAddendumtotheRFTP. Dave Eberle stated that ComRim International has expressed objections to the prequalification requirements in the RFTP. Specifically they object to the requirement for hydro experi- ence,and experience with hardware supply.The concensus of the Committee was that the prequalification criteria,if anything,was too loose,and should not be relaxed further. It was recommended that it be suggested to ComRim that they form a joint venture to obtain the necessary experience qualifications. C.SEI Stability Study Results A summary of the preliminary results of Phase 2 of the SEI Stability Study was discussed by CEA.David Burlingame explained that it appears that a combination of the 230kV Tine from Anchorage to Soldotna and reconductoring of the Sterling Highway line solves the stability problem.Another possibility appears to be the use of several large SVS instal- lations on the existing system.David Burlingame advised that the final report should be available by September 15,1988. The committee concluded that based upon the preliminary SEI study results the PMC should be advised that there are definite economic impacts as a result of system stabilitylimits.It also appears that the plant output restriction should be revised downward from 50MW to 40MW (20MW per unit).Final conclusions and recommendations to the PMC will be made after the final SEI report is reviewed. 4439/919(3) IV.NEW BUSINESS A.Reduced Generation Load Cases Dave Eberle distributed copies of letters from SWEC datedSeptember23,1985,and August 18,1988,(copies attached).The September 23,1985 letter showed the project energy at theoriginal(90MW)configuration.SWEC has rerun the loadsimulationstudyusing20MWperunit,25MW per unit,and 45MW per unit,the results of which are contained in the August 18,1988. It was noted that the results of the load cases were dependant on load data and curves provided by CEA in 1985 (Table A in 1985 letter).It was also noted by committee members that this does not necessarily reflect current utility thinking on how Bradley Lake will be used.CEA,GVEA,and ML&P will provide average daily load and monthly usage curves to update Table A in the 1985 letter.The curves will be based on 102MW and 40MW plant output limits.APA will have SWEC revise the generation load cases based upon the revised utility infor- mation.This information will then be used by Dick Emerman as part of his economic analysis of the railbelt alterna- tives/intertie study. B.Digital Governor As a result of the Committee's continued concern over the use of a prototype Fuji digital governor,and at APA's direction, SWEC had requested a quotation from Fuji to substitute a Fuji analog or a Woodward digital governor for the Fuji digitalgovernor.Dave Eberle distributed a letter (attached)dated August 19,1988,summarizing the information obtained from Fuji.If the Fuji analog governor is selected,the contract price remains the same but governor delivery is delayed by six months.If the Woodward digital is selected,the contract price is estimated to increase by $78,207 and delivery is delayed by 30 days.The Woodward digital governor proposed is the "501"single CPU system.It was noted that CEA of ML&P have several of the Woodward "501's"currently in operation. The Committee unanimously recommended that,due to the proven reliability record of the Woodward governor and the utilities experience with the same governors,APA should switch to the Woodward 501 governor.It was further suggested APA explore having the capability to upgrade to the 503,triple redundant governor in the future.APA agreed to proceed with finalizing negotiations with Fuji to switch to the Woodward governor. 4439/919(4) Communication Arrangement Ron Krohn distributed a copy of a sketch entitled "Project Communications",15800-E21-3.It shows the VHF and microwave channel requirements,the allocation for the temporary con- struction telephone system,and the future permanent communi- cations system.The committee requested that the transfer trip between Soldotna and Diamond Ridge,and the DECNET loop, also be shown.The committee further suggested that the allocation of spare channels on the state microwave system be investigated. Prequalified CGIS Vendors Prequalification proposals for supply of the compact gas insulated substation equipment were received from ASEA-Brown Bovari,Westinghouse-Mitsubishi,and GE-Hitachi.The GE-Hitachi system was not acceptable due to space require- ments.The other two have been approved as prequalified suppliers,either of which must be used by the Powerhouse Contractor for supply of the CGIS equipment. V.ADJOURNMENT The meeting adjourned at approximately 11:30 a.m. Attachments: Agenda Energy Generation Letter dated September 23,1985 Special Load Case Studies Letter dated August 18,1988 Proposals for Governor Alternatives Letter dated August 19,1988 4439/919(5) RECORD COPY fig be 'FILE NO MINUTES OF BRADLEY LAKE TECHNICAL REVIEW COMMITTEE October 12,1988 The meeting commenced at 9:00 a.m.in the headquarters building of the Alaska Power Authority in Anchorage,Alaska.The following individuals were in attendance: Ron Krohn,SWEC Steven Haagenson,GVEA Maynard Gross,HEA Tom Lovas,CEA. Myles Yerkes,MEA Dave Eberle,APA Afzal H.Khan,APA The proposed agenda was discussed by Dave Eberle.Item IV,"New Business," concerning election of officers and appointments to the Configuration Control Board,was moved to the first order of business.Dave Eberle and Myles Yerkes discussed recent PMC actions formalizing the TCC as a subcommittee of the PMC. Accordingly,officers,voting requirements,representation,and other issues requiring action were discussed.The Committee unanimously approved the following: 1.Dave Eberle -Committee Chairman 2.Myles Yerkes -Vice Chairman/Secretary 3.Myles Yerkes -Configuration Control Representative 4.The location and schedule of meetings would normally be established by the Chairman,however,the Vice-Chairman would also be empowered to schedule meeting locations and dates. 5.The APA representative and each purchasing utility are entitled to one vote on Committee actions. 6.Although the Committee will always attempt to reach a unanimous consensus,the Committee may approve an action by simple majority vote.Voting may not always be by formal roll call and,accordingly, each representative will be assumed in support of an action unless verbal difference is voiced at the time of the action. MINUTES of Bradley Lake Technical Review Committee Page Two October 12,1988 7.Committee actions would be summarized in writing by the secretary and forwarded to the chairman.The chairman will distribute copies to all representatives and provide a summary report to the PMC. Next,Dave Eberle presented a project status report.Key items included: 1. 2. De 6. The contractor is now approximately 200'into the tunnel using drill and blast methods. Change of govenor controls to Woodward has resulted in a net decrease in cost to the project. Spruce beetle control requires improvement due to recent community concerns.Additional control may be required as a permit condition at additional cost to the project. SCADA technical proposals are to be opened by APA on November 1,1988, and forwarded to SWEC for review and comment within approximately 30 days.CEA and HEA will be invited to review these confidential documents and have an informational representative attend the APA evaluation committee.Final specifications for dollar bids will be submitted to the TCC SCADA subcommittee for review and approval. Transmission line drawings and specifications for bid will be sent to all TCC representatives around November 1,1988. Bids for construction of the powerhouse will open on October 26,1988. Dave Eberle discussed his concerns regarding recent HEA discussions to delay construction of the Bradley Junction to Fritz Creek 115 KV transmission line. The following items were identified as potential impacts of this delay. Project capacity limited to less than 40 MW for stability reasons. Inability of system to adequately regulate HEA voltages south of Soldotna in the Homer area. Without this transmission loop,the project cannot be considered a "firm"generation plant in accordance with contractual considerations. Project communications and control were discussed in relation to future system stability requirements.It was agreed that adequate communications would be considered for unit tripping at Bradley and transfer tripping all Kenai transmission lines.CEA will provide SWEC with a copy of the latest CEA communications plan. Next,the Committee received the preliminary "Bradley Lake Stability Study -Phase II"from S.E.1.Discussion centered on the requirement for a 230 KV line or a combination of 3 SVS units on the Kenai.The report did : :( MINUTES of Bradley Lake Technical Review Committee Page Three October 12,1988 not completely present SVS unit requirements,but Dave Burlingame of CEA indicated that S.E.I.was able to achieve reasonable stability with a series of 3 SVS units.The Committee agreed to adjourn the meeting and reconvene on Monday,October 17,1988,beginning at 10:00 a.m.in APA headquarters,at which time a draft of the final report will be available for Committee review and action. Prepared By: Recommended By:LY KILDavidEberle,Chairman 767.1018.1 STONE &WEBSTER ENGINEERING CORPORATION SSSS GREENWOOD PLAZA BOULEVARDAENGLEWOOD,COLORADO 80111-2113 QDORES ALL COMED OEE 70 P.O.00x 5006.COLORADO 0217 5008wu.TELG 45.4401 RMATRDC W9) CuaTtaneaeca fastione usCrd?wt...Bs PerTLags.of cmrcaeo QCM ARS.WAryQeenwens.VAOanVERGanensiecePrLAUOEROALEFame,movetaa wasuneven o¢. Mr.D.R.Eberle October 28,1588 Project Manager Alaska Power Authority J.G.No.15800.45 701 East Tudor Rd.WP 15A Anchorage,AK 99503 SWEC/APA/2338 ELECTRICAL SERVICE 70 BEAR COVE POWERHOUSS CONSTRUCTION CONTRACT BRADLEY LAKE HYDROELECTRIC PROJECT We have reviewed the attached September 29,1988 letter from Homer Electric Association,Inc.regarding potential of Bradley Lake Bydroelectric Project as a future power source to HEA Bear Cove district circuit. in response,we suggest two alternative methods to provide power to BearCove. 1.Replace the Project Facilities transformer,ONPS-XAl,with a transformer rated to handle both the project facilities and Bear Cove load. 2.Add an additional transformer for the Bear Cove load.This transformer would be in parallel with the Project Facilities Transformer,ONPS-XAl.Attached is a sketch of the one-line arrangement for two transformers. If the existing transformer is replaced,the larger new one may not fit in the powerhouse,and would have to be located outside.If an additional transformer is added.it would also have to be outside. To facilitate locating a transformer outside,two spare 4”conduits have been added in the utility trench behind the powerhouse as shown on the attached drawings.Thies change was made in Addendum No.4 to the Powerhouse Contract. These methods were discussed by telephone on October 19,1988 with Mr. Oscar Johnson.Should you wish to discuss thie further please call JohnYaleormyself. N.A.Bisho Deputy Project Manager NAB/JE/CM ec:Ogcar Johbngon 14aius ston lahfapsten ine-1989 STOnd &WEBSTER ENGINEERING CORPORATION TO PROJECT FACILITIES REFER TO DWG FE-fU 4 ONPS -KAI PROJ FACILITIEWUsvcevemN TO BEAR COVE FUTURE SERVICECTYN)750 Kva.13.8-2.47KV FTYTY To BEAR COVE 3PH,GOHZ TO SCACA /DISPATCH TO SCADA/DISPATCH o-, "ea ("|BRKR OR DISCONNECT ;|BRKR OR DISCONNECTbyeSWITCHepeeSWITCH SN _/*>--_ 3ft 4000/5 A 3000/5A 3 INPS-ACB 30 )2NPS -ACB40 ane oe A zee A100/45Lave 00/5 PO sc| 100/5A on/ea LoC-OSwesrecenaenaoae®2 @ @ 4.J'ee DATE 10-73-44 TITLE!REP: PREP.Wf PROPOSED ONE-UNE 15800 -FE-|B-2 CHECK]§4 3 2 1 OF FUTURE SERVICE [sxEtcn arn To BEAR COVE ISB00-C -|3 &6215.9 - _o me a-me me APA 68-R 016 °ADDENDUM WO.5 October 19,1988S2CTIONIICRANGESTOBIDDOCUMENTSPageIIT-C -&C.Changes to Engineer's Orawirgs VOLUME 7 =DESIGN DRAWINGS (Continued) DRAWTNG NO.CBANGE 18800-FE-32A-1 Revise Section i-1 and add Detail A as shown below: SPARE ©60g 4725yc473ilyaCSPARECH . Ceeta7t SL ane FE AL AF RAC StS pyscugs PuNCe TS a KS,4 v CAP AND SEALCONOUITCHACHTSDETAILA.40 SH4C 473)Fr FRONTSOEEMHOOSEWALL. (18800/PH,ADD S$,5999R/273/L8] -meme ome me ee eweae a-e SPA=88-R-016 ADOENDCM NO.5 SECTION II =CHANGES TO BID DOCUMENTS Octcber 19,1988 C.Changes to Engineer's Drawings Page II -C-§ VOLUME 7 =DESIGN DRAWINGS (Continued) DRAWING NO.CHANGE 1$8600-¥E-446-1 Add conduits to area Aw?a6 shown below: U {c i i ]¥t zy) -.5 .eo a ay oe :wy Ageea .-ia ae tar.e 7 :.nn |f = 3 . : (15800/PH,ADD S$,$999R/273/L8} i=%©)S22 °ON 2SnSad «ESPeNOLS O2:St 66/B2-Bt sree CT OS (OB Ldtdd BECHTEL Civil.IMC,SO7zrSedde P.o3 Homer Electric Association,Imc. CENTRAL OFFICE.IO77 LAKESTREET ©HOMER,ALASKA $0603 @ (007)236-8167 AECORD COPY September 29,1986"ENO RECEIVEDPry Mr.Dave Eberle a oCcT 4 1988 ALASKA POWER AUTHORITY "701 Bast Tudor Road AUTHOR!. P.0.Box 190869 ALASKA POWER KEY WORDS: Auchorage,AK 99519-0869 REFERENCE:Potential of Bradley Lake Hydroelectric Project ag Puture Power Source to BBA Bear Cove District Circuit Dear Dave: ° Reaidenots from the community of Bear Cove have approacned domer Blectric Association,Inc.to explore the possibility of exteodiog a distribution line from tne Bradley Lake Hydroelectric project to their homes, Last week I apoke to Stone &Vebster on an 'taformal basis toinquireofpoassioleexistinglocationsornecessaryactions required to design into the power station a future "tap"shouldtheBearCoveareaelecttoproceedwithalineextension. Ron discussed several alternatives that could possibly be considered aad suggested this letter be eritten asking for a formal response trom Alaska Power authority. For plananiag purposes,an anticipaced load between one to twoNEZAWATLTS218delogpiannea.i{n View or tne Lact that tne power.nouse will be bid shortly,we understand that if any changes vere made,they most likely would occur as a "change order®. Ia my brief discussion with Ron,we discussed the following eptions to provide Homer Electric with the future power source: 1.Expand the project facilities services transformer No. 1 from 7SOKVA to 1,5MVA.Tn addition,provide ano additional switch cabinet adjacent to the facilities switch gear for a future "take off"point for HEA. 2.Or,provide a four (4)way tap with spare conduit that eould allow the future addition of a service transformer that would be daedierted to Homer Electric (Bear Cove circuit). 3.Or,possible addition of a 113KV breaker arrangementWithinthesubatationtoprovideafuturesource(cap)for the addition of a Gistribution eubstation. SAT OS °S3 14515 BECHTEL CiviL,a.Wr7ewedis P.3-3 Page 2 Dave Eberle September 29.1988 T'm sore there are other possibilities that have scot been considered that may provide an economical option to Homer Electric should we proceed with the distribution circuit. Cur intereat ia that,prior to construction of the power house, we Would like to pursu@®our options and algo insure the projectdesigncouldfacilitatetheanticipatefuturegrowthazdescribed above.. We would welcome your comments and cost analysis of the various options available to us. Sincerely, -_-_oeeOu Tom Smail Manager,Oo.&&. APABRCOV .TSS:kr oo:Keat Wick,Manager RBA Ron Krohn,Stone &Vebdater Norm Story,Homer District Nanager,REA Osco, Swas Fenas on /5 mec i renalPueSASERENTGSiTPersraeeCorrathednst"wre)ae D agat?Des weve ( rw.oor aan armens fin A Coen eid bie ©oe tn4 paar ase .RN ame| Drvk meeee Steve Cowper Goverror N Alaska Power Authority State of Alaska November 7,1988 Mr.Sam Matthews Homer Electric Association,Inc. P.O.Box 429 Homer,Alaska 99603 Subject:Bradley Lake 115 kV Transmission LineBradleyJunction-Wood Pole Structure Dear Mr.Matthews: In response to your letter of October 12,1988,we are confused by thislastminutechangeonthepartofHomerElectric(HEA)when the biddocumentsfortheBradleyLakeTransmissionLinesarenowreadyto beadvertised.The configuration of the poles and steel towers at BradleyJunctionwerereviewedbytheTechnicalCoordinationCommitteeand modified per HEA requirements several years ago.At that time HEAdictatedmodificationswhichrequiredanadditionalsteeltowerto be added to each Bradley line.It was also agreed that HEA would construct the wood pole portion of Bradley Junction. These changes were made solely to accommodate HEA's design.Since that time there has been no indication from HEA that other modifications would be required until-your-recent letter.It is unreasonabletosuggestthatwemodifyourconstructioncontracttonowincludethe installation of wood poles.The Bradley 115 kV lines are steel towers supported by driven steel piling.Our contractor will not have the necessary equipment to install wooden poles in augered holes.To include these few wood poles would require the costly mobilization of additional equipment.Since HEA's Fritz Creek -Soldotna Transmission Line is a wood pote line,it is certainly more reasonable to have HEAinstalltheTH-5A structure at Bradley Junction...which HEA agreed to doseveralyearsago. We believe that HEA should continue to install the wood poles at Bradley Junction.If HEA insists that the Power Authority build the wood pole interface the wood structures can be added to our contract as an optional bid item however,such added cost would have to be reimbursed by HEA. David R.KEL Project Manager DRE:tlj "-PO Box AM Juneau.Alaska 99814 (907)465-3575 Mm PO Box 190869 704 EastTudorRoad Anchorage.Alaska 99519-0869 (907)561-7877 4256/914(1) $75afoug Tepoadg 'ualvury BNBYUZZEN WES o meeeame -+2 ._ ee ee ee on ee aed 'AL asaours *gaoR4juo?STU wo}SUOTQBPOTZyISads pur STtesap ayy Gurzrpeuty mou aue am aours Apasetpawt sn yoequoo asratd UOTZRPITZIUBTD uayyuny paeu wo suotzsanb Aue aaey pinoys 0A 3] "BANFONUYS YDFIMS BYS O4UL PuapeBD pur *BuUtuys HTNOD am sunzonuys Udi 43 4H uozseugquod wnNoK UeYyy 4dQeT BBATAUE YSH J]°3TNoutS BY2 O4UT BUNQINUGS BYZ BIZ PUR BuN{NAyS 4aS--usagqur ayz pring PINGS wOZOeuguEd ANOA °S¥un{oN43zS O43 uno UdeNgeq autm Buru4ys PIhom am |tnpauss unok of uctud vorzouns ayy 3e aq Ya PINoYS "uotseutpucod 3yroqe Azuom 04 aARy qou Our Sunganuys YIITMS asaTCdMOS ayy Op 09 MCA mOl[Te [TIM apts yore uo spuapesp Surazas ung °,suau30 Ag,aungonusys STUUR SMOUS Burmeus SAoQe auL "L/e2 OUR 9/42 SBUNIINUIS WOH BU UsS|MgaQ uedsS PIW anoge 438 aq TTIM sun3zonuss UDITMS LOT{5UNE AaTpPeug unoA Butpugasuapuh uno Sf 372 °S.uo-HL @Q U20"TTIM 2Z/w2Sad DUR 9/¥25C SIUNIINAIS BUL "BUN|QDNUYS 39S ABAUT (Udy)VOT3Sunf AatTpeuq aug $O @PTS UBUZTS UD SAUuNdonuys (2)OM}Yonugsuod O39 ave sueTd uno *snafqns aduauajyau ayy uog surtd uoTaoNuasuod uno azyueuwns pue 4uesuf uno Ajrurer>03 yuvquodut $1 uasgat Stud Taay an G8-OT-%¥NOILINULENOD WOs-anssy peurbrug 3-@0S-GaMS-OMd snyey 9 uapkug T-UBCE-33-OOGST-OMG 4998GamM F BUSRS iButmeup Buymorros 243 3O Mataau ug *uotsgouns ene Aappeug 92 Pecy ene]FueNNgsn,"eEenzgeq ous UOrTssTwSUPA) AXSI}#43 30 quewBes 3743 soy SuoTQeaoTytSeds pur surtg uno BZU(PuULly OF FUBSQZLNSUCS UNO UIE Supyuom ueeqg SArY OM NEEM STUL S'enaeq ueeg UOTSOUNE aHey AaTpeug ay SBtattoe4 UOTSSTWSURAL AYGTT Udd/UBH JO YOTQEUTPuoO)puy aoesuaquy 13Y E9CQ-E5S66 PNS@ly 'sheucusuy 63826T *OG °O "A proy voon,°3 102 Aqraouanyy amog eusety @t4aqg praeg 'aw e863 'St 43890350 /f *d Wwi10L STR STR 0S24/6 BRADLEY DS24/7(HOMER)JUNCTION (HOMER) (APA) HOMER tow 280° SOLDOTNA - TH-5A STONE &WEBSTER DWG-I5800 -FE-328A-|DRYDENG&LARUE OWG SWB9-500-I ORIGINAL ISSUE FOR CONSTRUCTION 4-|8-88 HEA/GC OWG.2002 SH.13 SCALE={''=200'HI"=20'V October 19,19338 RECEIVED 2y RECORD COPY FILE NO Matanuska Evectric Associationnc PRe P.O.BOX 2929 TEL:(907)745-3231 163 EAST INDUSTRIAL WAY FAX:(907)745-9328 PALMER,ALASKA 99645-2929 WAS*” "g8 Oct 21 P6:40 Mr.David EberleAlaskaPowerAuthorityP.O.Box 190869701EastTudorRoadAnchorage,Alaska 99519-0869 Dear Mr.Eberle:Subject:Bradley Lake Technical Coordinating Committee (TCC)RepresentationThisletteristotormallydesignateMr.Myles C.Yerkes and Mr.Kenneth E.Ritchey,respectively as primary and alternate MEA representatives to the TCC.Please address all correspondence to Mr.Yerkes at the tollowing address: Mr.Myles C.Yerkes . Matanuska Electric Association P.O.Box 2929Palmer,Alaska 99645 _Sincerely, ames General Manager MY:BB 358-1.1019.1 ccs Ken Ritchey Myles Yerkes CORRES PONDENCE DISTRIBUTIONACTION:COFIES: (Fete) Due Date: ALASKA'S FIRGT BEC IM RARAAR Aen et HECOHD COPY FILE NO. Main Office (907)224-3331 Police (907)224-3338 Harbor (907)224-3138 Fire (907)224-3445 Telecopier (907)224-3248 -om oy getosmeeé -"e s.- CITY OF SEWARD 9.0.8OX 167 SEWARD,ALASKA 99664 September 1,1988 9-013-88-501 Robert E.LeResche Executive Director "ce gg ssa Alaska Power Authority "tees P.O.Box 190869 ALASKA POWERAnchorage,Alaska 99519 AUTHORITY KEY WORDS:RE:Bradley Lake Project Management Committees Dear Mr.LeResche: This letter is to reaffirm the individuals designated to represent the City of Seward on the Bradley Lake Project Management Committees. Committee Member :Everett Paul Diener,Manager of Engineering &Utilities Technical Coordinator Sub-Committee;Jack Anderson P.E.,Electrical Engineer Finance Sub-Committee:Robert Peirson,Finance Director Mr.Peirson will represent the Seward Electrical Utility on the Rating Trip to New York. Sincerely, --?s Everett P.Diener CORRESPOMDENCE DISTRIBUTIONManagerofEngineering&Utilities ACTION:COPIES: ce:Anderson Peirson 501 File :Kc.'B.fetus Due Date:D.Shinke J.Beer- RECORD COPY FLENO .|-RG (eG EXomer Electric Association,_Inc.___ CENTRAL OFFICE:3977 LAKE STREET @ HOMER,ALASKA 99603 @ (907)235-8167 7 oe -,.eu : November 3,1988 reves & Nov4 1988 Mr.David Eberle eR AUTHORITYALASKAPOWERAUTHORITYALASKAPOWE 701 East Tudor Road P.O.Box 190869 Anchorage,AK 99519-0869 REFERENCE:Response to Bradley Lake TCC Meeting 10/12/88 Dear Dave: In response to your Technical Coordinating Committee (TCC) meeting on October 12,1988,please be advised that the following Homer Electric Association staff members have been designated to represent HEA on the Bradley Lake (TCC): Primary Member Sam Matthews Alternate Tom Small Sincerely, HOMER ELECTRIC ASSOCIATION,INC. Tee SmZaB.Kent Wick Manager APATCCMT.BKW:kr :Sam Matth N "ACTION:° /Ficé) |_4 cc]Jue Date: rite NU =s ef 3.VAG G % Homer E:lectric Association,Inc. CENTRAL OFFICE:3977 LAKE STREET @ HOMER,ALASKA 99603 @ (907)235-8167 Ce aa wet'ulNovember2,1988 ' NOV 4 1988 Mr.David Eberle ALASKA POWER AUTHORITYALASKAPOWERAUTHORITY 701 East Tudor Road P.O.Box 190869 Anchorage,AK 99519-0869 REFERENCE:TCC SCADA RFP/HEA Selection Committee Representative Dear Dave: In response to the October 12,1988 TCC meeting,HEA has designated our Mr.Maynard Gross to represent HEA on the above referenced committee. It is our understanding that three to five days will be requiredforthisaction.We would request that at least one week notice be given prior to this meeting to schedule his participation. Sincerely, am Matthews Manager,Major Projects APATCCMT.SCM:kr cc:Kent Wick CORRESPONDENCE DISTRIBUTION ACTION:COFIES: [Fré) Jue Date: MEMORANDUM October 31,1988 TO:Jim Palin Ken Ritche ”Le SUBJECT:OUTSTANDING AEG&T/HEA ISSUES AND CONCERNS You asked me to prepare a listing of concern items which should be discussed ifadditionalagreementwithHEAisrequiredtoprovideforconstructionofthe Bradley Junction to Fritz Creek Transmission Line.In preparing this list,I solicited review and input from ML&P,GVEA and CEA engineering types.Many items are covered by existing agreement and may only require some "purification.”Other items may require substantial discussion.The items are briefly summarized as follows: wv 1.Control of HEA transmission facilities related to Bradley Lake power flows. A.Soldotna Substation B.Soldotna Capacitor Bank C.Soldotna Unit No.|(Generator Dispatch) D.Diamond Ridge Substation E.Fritz Creek Substation F."Permissive Control"definition rp7Ott +heres 2.Interface with HEA proposed SCADA system A.Soldotna (CEA) B.Homer (Bradley Project) C.Diamond Ridge (CEA) D.Scheduling of work E.Operations and Equipment specifications 3.Access to Another Utility Station A.For manual Operation B.Maintenance (Rounns ¢jun kegel)8 *MEMORANDUM:OUTSTAN NG AEG&T/HEA ISSUES AND CON ERNS Page 2 October 31,1988 4,Bradley Lake O&M definitions -Resolution of HEA problems 5.Cost/schedule agreement to allow completion of the Bradley Junction to Fritz Creek Transmission Line prior to Bradley start up. 6.AEG&T/HEA communications and control requirements for O&M A.Cost/Schedule for Construction of a communications drop into Homer B.Project control/monitoring terminal in Homer 7.Coordination of protective relaying systems A.Closing of 69 KV transmission "loops" B.Ground fault relaying on the Tesoro Interconnection C.Interface with CEA and Bradley relays D.Future relays and coordination policy 3.'Detinition of acceptable voltage,frequency,watt and var limits onHEAsystems. A.Normal and emergency criteria B.Load balancing C.Harmonic correction D.Capacitor compensation in Homer 9.HEA wheeling and other costs tobe billed to utilities as a BradleyO&M cost A.Transmission line wheeling B.Transmission Line O&M costs C.Substation costs.TI £2D.Communication system changes Jae US Mhvcer E.SCADA system charges Ls los F.Overhead and margin charges ,Af,.WZ7 ZEL .ike Yerkes bb/358-1.1031.1,o2 -- 'a ' -vzi'or Steve Cowper.GovernorpyN Alaska Power Authority ,State of Alaska &4,APA/OTHR/0841 '2.L)Pe &Op.May 18,1989 BSS.Sica Mr.David Burlingame Chugach Electric AssociationP.O.Box 196300-Anchorage,AK 99519-6300 Subject:Bradley Lake Hydroelectric Project SCADA Subcommittee Meeting and Technical Coordination Committee Meeting June 1,1989 Dear Mr.Burlingame: Meetings of the SCADA subcommittee and the Technical Coordination Committee (TCC)will be held at the Alaska Power Authority on June 1, 1989.The SCADA subcommittee meeting will begin at 9:30 a.m.,followed by a meeting of the full TCC at 1:30 p.m.Attached are the proposed agendas along with the minutes of the March 30,1989 TCC meeting. The primary purpose of the TCC meeting will be a discussion of the proposed plan for the development of the "non-intertie”solution to the system stability problem.We will also review the proposed scope of work for additional system studies and specification preparation by PTI and Stone &Webster. Please notify appropriate individuals within your organization of the upcoming meetings. Sincerely, LSKEL David R.Eberle Project Manager DRE:it cc:Mr.David Highers,Chugach Electric Association ct.PO.Box AM Juneau,Alaska 99844 (907)465-3575XKPOBox190869704EastTudorRoad=Anchorage.Alasko 99519-0869 (907)561-7877 5795/0D54(2) I. IT. Ill. IV. V. AGENDA Technical Coordination Committee Meeting SCADA Subcommittee Bradley Lake Hydroelectric Project June 1,1989 9:30 a.m. at --Alaska Power Authority Adoption of Prior Meeting Minutes Approval/Modification of Agenda Old Business New Business A.SCADA Proposals -Step 2 Competitive Pricing B.Evaluation of SCADA Optional Items 1. DECNET Interface 2.BBC Protocol Interface 3.Dynamic Test of RTU3 4.Five Year Warranty Adjournment LINCAINNCAIaA\ AGENDA Technical Coordination Committee Meeting Bradley Lake Hydroelectric Project June 1,1989 1:30 p.m. at Alaska Power Authority I.Adoption of meeting minutes II.Approval/Modification of Agenda ey Business cyeres Ayer A.PTI Stability Studies -RFP for Continued Work 1.Task 1 -Completion of Stability Studies 2.Task 2 -Engineering/Supply of Equipment 3.Task 3 -Studies/Specifications for Kenai System IV.New Business A.SCADA Subcommittee Report and Recommendations B.Gourrar V.Adjournment BRADLEY LAKE PROJECT TECHNICAL COORDINATION COMMITTEE MINUTES OF MARCH 30,1989 MEETING The meeting came to order at 9:30 a.m.in the Anchorage officesoftheAlaskaPowerAuthority.In attendance were: Mike Yerkes MEA John Yale SWEC Dave Eberle APA Afzal H.Khan APA David Burlingame CEA Paul Johnson CEA Fred LeBeau GVEA Steven Haagenson GVEA Tom Small HEA Maynard Gross HEA Sam Matthews HEA John Cooley ML&P Minutes of the previous March 2 and March 10,1989 TCC meetingswereapprovedwithminorcorrections. The meeting agenda was approved after adding a report on the APA transmission line bid status under old business. Next the SCADA Subcommittee distributed documents and discussed the results of their evaluation of SCADA technical proposals.John Yale reviewed the following documents with the Committee: 1.Trip report "SCADA owners site visits" 2."Reasons for rejecting HSQ's proposal" 3."Exception or clarification"listing by vendor 4.Section 2.0 "technical specification"of the SCADA Invitation to Bid (3/24/89 date) Following discussion,the Committee unanimously voted to accepttheSubcommitteerecommendationwhichfindstheHSQtechnical proposal unacceptable due to critical technical deficiencies and finds the other proposals as acceptable subject to compliancewiththelistofexceptionsandclarificationforeachrespective proposer. BRADLEY LAKE PROJECT TECHNICAL COORDINATION COMMITTEE MINUTES OF MARCH 30,1989 MEETING Page 2 Following Committee action,APA advised formal SCADA biddocumentswouldbecompletedandmailedtosuccessfulproposerswithinapproximatelytwoweeks.Formal bid opening is tentatively scheduled for May 4,1989. Next,APA distributed a memorandum of March 15,1989 and a memorandum of March 16.1989 from Harrison Clark of PTI to Afzal Kahn of APA.'The memorandum of March 15 responded to the TCC listing of March 10 which summarized additional required work onthenon--230 KV -intertie option.This memo also provided a budget for PTI to complete the additional work.The memo ofMarch16discussedadditionaltechnicalissueswithproposed "brakes"and "stabilizer controls."Dave Eberle stated APA's intention to complete this work by allowing Stone &Webster toemployPTIasasubcontractor.The additional work will be delayed to consider legislative action on the 230 KV alternative, since the additional work will require re-direction if the 230 Kv"Southern Intertie”is approved.In any case,additional PTI costs will be capitalized as a project cost. John Hale discussed the recent meeting with PTI,Woodward Govenor,and Stone and Webster.Apparently,an agreement on thevalidityofthePTIGovenormodelwasnotachieved.Woodward will prepare a model and provide same to PTI in the future. Dave Eberle noted that Newberry Electric has been awarded theBradleytoBradleyJunctiontransmissionlinecontract.The low bid was determined "non-responsive"due to a lack of an Alaskan Business License by one of the venture partners.APA questionsifNewberryorthelowbidderareentitledtothe5%"Alaska Bidder Preference."Four formal protests from bidders have beenreceived.APA hopes to have all protestors stipulate to waivetheadministrativeprocessandimmediatelysubmittheprotesttoacourtoflawforabindinglegalreview. SUBMITTED: YERKES,SECRETARY APPROVED: DAVID EBERLE,CHAIR MY:BB 302A.033189.88 wI@R-16-8 9 TeHL t7 354 ert. MEMORANDUM Date:March 16,1989 To:AFZAL KAHN From:HKC Re:BRADLEY LAKE BRAKING RESISTOR CONTROL AND STASILIZERS Afzal,I've been talking to Steve Balser (Schenectady PTI)about the Bradley Lake braking resistor control requirements,and the need to reduce stabilizer output while votages are high.The following are our conclusions at this point: The brake contro!requirements have expanded.We now plan to uss the brake to limit overspeed following loss of the tie to Anchorage and to maintain first-swingStability.We also have two brakes to Improve reliability.'With these expanded functions,the stabillzers do not appear to be the most economic approach or the best technical approach for several reasons. Hence at this time we suggest applying stabillzers modified only to provide thereducedoutputwhenvoltagesarehigh.This modification would push the total cost of two stabilizers ($100K)up to about $110 to $115K (including dalivery,tuning,site checkout,etc.).Data logging in the stabilizer would add another $5K each,but may not be necessary if monitors are used as outlined below.The data logging function In the stabilizer Is limited to information available within the stabilizer (e.g.power,voltage,and speed),while the DSM can pick up many quantities Including breaker operations, turbine trip signals,etc. We thus suggest that our Dynamic System Monitor be used for monitoring and brake control.The monitor has probably the best low cost digital frequency transducer available In the industry (it is better than our stabilizer and is now being used by EPRI "|think |suggested at one point that we Could apply just one brake for the lessordisturbances.I've reconsidered this.Though just one break would match mostdisturbancesbetterthantwo,the brake will be more reliable if we always apply both,and then take them off more quickly (e.g.two brakes for .2 seconds rather than onbrakefor.4 seconds).This way,if ana fails to go on,the other will stay on longer anddothejob.This will work for all but the worst-case event,a three-phase fault closetoBradley(Bradley-Soldetna line)under high Bradiey power and high export. 1 tAR-16-89 THU 17:53 PT? for some very critical monitoring at HVDC converters).In addition,the monitor has software based triggering that can be custom programmed,and thus provides a programming environment that is Ideal for the brake control functions.The brake control software would simply Initiate brake-on or brake-off signals instead of,or in addition to,starting the monitor.The monitors nin about $30K each in standard form. We suggest that two should be used to match the reliability of two braking resistors (9.g.two monitors and two brakes,but with each monitor serving both brakes). Dave Burlingame has information on our monitor and is evaluating it for several locations.He and |have talked about the benefits of it for Soldotna and Bradiey.It would give output very much like the PSS/E simulations we are doing (in tact the results of recorded disturbances can be plotted on the same page with PSS/E output or plotted for comparison with output from any other stability program).Whether or not a disturbance Is simulated,recording it (voltage.power,reactive power,current, apparent impedance,etc.)can tall haw the system responded,what kind of instability occurred,etc.The monitor can record for up to 10 or 15 minutes after being triggered. It is smart enough to trigger on subtle events such as rising or dropping frequency, _Duliding oscillations,In addition to voltage dips,fault currents,etc.tt can have minutes of pre-disturbance recording.so can give much Information on the pre-disturbance situation.It is quite unique,and complements DFR (digital "oscillographic"recorders), and the Schweitzer relays Chugach has (these devices either only record for a few seconds,or are hard to extract stability Information trom when they are equipped with enough memory to do a minute or more).The monitor can be accessed by modem. i think |gave you some Information on it,but I'll send you some to be sure. mat whne vollace collapse rs+Jwelk inpo Sleady Ss)slebilih,ane.poten aL RECEIVED JUL 31 1989 ALASKA ENERGY AUTHORITY. BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE (TCS) MINUTES OF JULY 17,1989 MEETING The meeting came to order at 1:30 p.m.in the Anchorage offices of the Alaska EnergyAuthority(AEA).In attendance were: Dave Eberle AEA John Yale SWEC John Cooley ML&P David Burlingame CEA Tim Newton CEA Afzal H.Khan AEA Mike Yerkes MEA Steven Haagenson GVEA Minutes of the previous June 1,1989 TCS meetings were approved with minorcorrection. The meeting agenda was expanded to include reports on transmission line status (OldBusiness),Surge Tank Analysis (New Business),and CEA RTU provided at Project Site -(New Business John Yale distributed various govenor control stability study plots including asummary.The Committee discussed this work and contractual requirements in detail.Although the plots indicate stable project operation in these cases,system dampeningmaynotalwaysmeetformalcontractrequirementsandtheCommitteewouldnotrecommendrelaxinganycontractualrequirementsatthistime.The Committeeconditionallyacceptedthestudy.Additional analysis may be required following thePTIstabilityanalysisanddesign. HEA is now moving ahead to construct the Soldotna -Bradley Junction -Fritz Creektransmissionline.will delay constructing a 5 mile section near Soldotna toexpediteconstructionofthe13milesectionbetweenFritzCreekandBradleyJunction. A intends to award a contract to Irby Construction for construction of the 28 mile section between Bradley Junction and Soldotna.Significant items include: 1.REA and the HEA Board have approved this plan. 2.The shortage of power poles in the Pacific Northwest will delayconstruction.HEA is attempting to place material orders now. 3.HEA will use available resources to complete the lower 13 mile projectfirsttoprovideconnectionwithBradleyforinitialtestingandstartup.Work on this section will begin this Fell with completion in early 1990. BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MINUTES OF JULY 17,1989 MEETING Page 2 4.HEA is now working with Irby to resolve the lawsuit,determine a revisedcontractamountreflectingprojectdelaysandfinalizeanagreement. Dave Eberle indicated that AEA has formally awarded the project transmission lineconstructioncontracttoNewberrywhoisnowmobilizingandorderingequipment.Although the administrative project review process found AEA correct in awarding toNewberry.the low bidder is now appealing to the Supreme Court to halt work andreceivethecontract.Their efforts to date have not been successful. Next the Committee considered the draft "Engineering Services Scope of Work forSystemStabilityStudiesandEquipmentSpecifications”including related draft scheduleandbudget.e Committee conditionally approved the Scope of Work subject tovariouschangesdiscussedduringthemeeting.Mr.Yerkes as Project ManagementCommittee(PMC)technical representative will work with AEA to develop a revisedScopeandbudgetwhichwillbebroughtbeforetheCommitteeforreviewatalater te. During the last PMC meeting,AEA was requested to provide an analysis and briefingofthebenefitsversuscostsofasurgetankatthepowerhouse.Stone &Webster hasdelayedthisworkinanattempttofinalizeotherimportantwork.The analysis shouldbecompletefordiscussionwithinthenext30days. CEA has proposed by letter to AEA of July Ll,1989,to provide a CEA RTU at theProjectsiteatnocosttotheProject.e Committee delayed acting pendingrecommendationoftheSCADACommittee. The meeting adjourned at 5:30 p.m. SUBMITTED:LE fe (--- :YLES C.YERKES,VICE-CHAIR APPROVED: DAVID EBERLE,CHAIR MY:BB 302A.072089.204 STUDY PLAN SYSTEM STUDIES,SPECIFICATIONS,AND BRAKE AND STABILIZER HARDWARE AND SOFTWARE The following study plan outlines the work elements and schedule for the following five tasks: Task 1 Braking Resistor Specifications Task 2 Field Tests Of Existing Kenai Machines Task 3 System Stability Studies and Equipment Specification Studies Task 4 Preparation of Equipment Specifications:Statice var system (SVS),scries capacitors (SC),Stabilizers,and Monitors Task §Power System Stabilizers and Monitor/Braking Resistor Controllers Power Technologies,Inc.Page 2 TASK 1 --BRAKING RESISTOR SPECIFICATIONS Schedule:June 20 -June 29 Engineer:Harrison K.Clark Objective:|Prepare draft braking resistor specifications describing both electrical andmechanicalrequirements. Criteria:The braking resistors shall be robust and long-lived,and have the capacity necessary to provide first-swing stability and help limit system overspeed to 61.5 Hz following loss of the Kenai-Anchorage tie during heavy Kenai export. Report:The draft resistor specifications will be submitted to John Yale of Stone and Webster by June 29th. Budget:$3,000 Status:Complete,and within budget. Power Technologies,Inc.Page 3 Schedule: Engineers: Objective: Criteria: Report: Budget: Status: August 20 --September 30 Lou Hannett,Steve Balser.Lou and Steve will perform field tests,Lou wil! develop machine,governor,and exciter parameters from the test results. Run tests to define generator reactances,time constants,and saturation characteristic.Also run tests to determine turbine-governor response to Yising and falling frequency,and exciter response to changes in system voltage.Prepare complete stability models including turbine,generator, governor,and exciters. The models shall include sufficient detail to ensure accurate studies of first- swing stability,damping,and system response to loss of the Kenai-Anchoragetieduringimportorexport. A report will be prepared.It will discuss the test procedures and results,and will include block diagrams and tabulations of generator,exciter,and governor data derived from the test results. $27,000. This task is underway and on schedule.Because of turbine-generatorauxiliaryequipmentfailures,some machines could not be tested on schedule.The delays occurred while PTI engineers were in Alaska, and have added to the task cost.The total expenditure is nowanticipatedtobeabout$35,000. Power Technologies,Inc.Page + Schedule:October 15,1989 April 15,1990 See attached Task 83 study organization chart.The chart shows the opportunities toconductsubtasksconcurrentlyinordertoreducestudyelapsedtime.However,conductingworkelementsinSubtaskAconcurrentlymayincreasetheoverallstudyeffort.Forinstance,in Subtask A,elements 3 and 4 are shown concurrent with elements 1 and 2,yet elements 1 or 2 could rule out the need for elements 3 and 4 if either rule out the useofSCs.Similarly,any effort on elements 5 and 6 could be wasted if 1,2,3 or 4 show SCstobetootroublesome.: The Subtask A work is estimated to require a maximum of 8 weeks of elapsed time.IftheSVS-SC alternative is shown to be a problem early in Subtask A,then Subtask Acouldentailaslittleas4weeks.Some time between Subtasks A and B may need to bereservedformeetingsandaformaldecisionbetweentheSVS-SC and Two-SVS alternatives.However,this time should be minimized to the extent possible.Subtask B will require about 16 weeks,including draft report preparation.The total time for Task3willbeabout29weeksincludingreportcommentsandpreparationofafinalreport(thisisthesametotalscheduletimeindicatedforTask8intheEngineeringServiceScopeofork), Engineers: Greg Brownell,John Doudna,Lou Hannett,Steve Lambert,Harrison Clark Obiecti &Criteria: The Task 3 objectives include: )Choose between the SVS-SC and Two-SVS compensation alternatives, )Perform all necessary studies to fully define equipment requirements and operating procedures for the selected alternative. The stability and voltage control requirements have largely been set forth in previousstudies(Railbelt Stability Study by PTI,March,1989).These requirements are to be metintheselectionofacompensationsystemandthefinalsystemdesignworkdescribed below. Power Technologies,Inc.Page 5 The decision between SVS-SC and Two-SVS alternatives may be based on technical considerations or cost considerations,or a combination.However,because technical differences may be decisive,they should be addressed first.If technical differences are notdecisive,economics can be considered.If we address the technical issues in descending order of their likely impact,we may be able to make a decision without considering all technical and cost issues.A suggested decision process is: 1 Do SCs give untenable SSR problems and/or aggravate SVS SSO problems?If the problems are untenable,the decision can be made at this point tn time to go with Two-SVS.If the SSR problems Icok solvable,go on to the next step. 2 Are there solutions to the SSR problems?Jf the problems are not too severe,and there are acceptable and modest ccst solutions,then a decision can be made at this point to go with an SVS-SC scheme.If the problems and solutions are not decisive, go on to the next steps which involve reliability and cost issues. 3 Is bypassing required?If not,then the cost of the SCs is significantly reduced, increasing their attractiveness. 4 Is TRV a problem for existing circuit breakers?Jf not,then the SCs are more attractive yet. 5 How much more robust is the SVS-SC scheme than the Two-SVS scheme?SCs require less operator attention,less maintenance,often will hold a system together through more severe disturbances than an SVS-only scheme,etc.There are also disadvantages,for instance,backswing overvolteges are more severe in an SVS-SC scheme than a Two-SVS scheme.If a comparison shows significant advantages to SCs,then there is further reason to go this route. 6 Equipment availability/feasibility:Visit manufacturers to confirm necessary equipment is available,visit other utilities with series capacitor and SVS experience. If step 1 shows untenable problems,and high risk even with remedial protective systemsinplace,a decision in favor of a Two-SVS scheme can be made at that point.If SSR is not a problem,then the SVS-SC scheme can be selected at this time.If a choice is not indicated after step 1 (ie.,SSR is a problem,but appears solvable),step 2 will indicateifSSRcanbesatisfactorilycontrolled.If at that point the choice is still not clear, additional information can be developed in steps 3 through 6 as necessary.Steps 1 and2areessentiallytechnicalissues.Steps 3,4 and 5 are economic issues.Step 6 addresses the issue of confidence in the selection. The order in which steps 3,4 &5 should be tackled is open for discussion.To reduce elapsed time and to make the most well-informed decision,all three could be pursuedconcurrently,and the decision made with input in all three areas.The sixth element hasbeendiscussed,and may also provide useful input. SUBTASK A 2 SSR SSR SOLUT. SUBTASK B SELECTSVvS/SCORTwO-SvSa3 SUMM.STAB. 15 NEW 138kV '6 OP.PLAN !6SHORT-CKT SC MOV TRV 3 2 3 4 SSR $so OPT SVS/SC 8 9SVSCTRLPROT. 14 10) BSLAND RAKE /DEFL ? VOLT CTRL 12 HARMONICS rr SVS LOSS TASK 3 Study ¢ganization Power Technologies,Ine.Page 6 The operating plan is not included in the above list of critical issues.However,theelementsoftheoperatingplanimportanttoacomparisonofSVS-SC and Two-SVS wouldbecoveredinstep5oftheaboveoutline.Such elements would be considered for bothSVS-SC and Two-SVS schemes in the above plan,and would thus provide a comparison.Additional elements of an operating plan could be added for a more complete comparison. SubtaskAatudieg --To choose between SVS-SC and Two-SVS alternatives. 1 SSR frequency and time domain analysis:Do frequency domain analysis todetermineifsystemresonancesundernormalandcrediblecontingencyandemergencyconditionscoincidewithnaturalshafttorsionalfrequencies,and levelofdampingateachsuchfrequency.Do this for Bradley,Bernice,Soldotna,andCooper.Then do time-domain studies to assess shock-torques from faults andreclosing.Determine if the magnitude or decay period can be damaging. 2 SSR solutions:Run cases to examine various solutions such as phase-wise compensation,SSR relays on generators,changes in compensation level (increaseordecrease),operating limitations,SVS supplementary control,ete.Determine feasibility and sufficiency of the solutions. 3 SC bypassing:Run critical short-circuit cases to determine fault currents through capacitors for worst-case operating conditions.The need for bypassing,and the type of bypassing where it is needed will be established based on fault level,impact of slow reinsertion on stability,cost of capacitors versus bypassing equipment,ete. (Triggered gaps are low cost and can reduce required capacitor ampacity,but give slow reinsertion.MOV or more capacitor ampacity to avoid bypassing provides fast reinsertion but is costly.) 4 TRV duty on circuit breakers:Digital switching surge analysis will be run to assess the transient recovery voltages imposed on circuit breakers that may have to interrupt faulted series compensated lines under normal or backup clearing conditions,The cost of moving,replacing,or upgrading circuit breakers (if necessary)will be estimated. 5 Robustness:The SVS-SC and Two-SVS schemes,designed to meet the same basic criteria will be compared for a range of disturbances beyond system design criteria. Examples include longer duration faults on the Bradley to Soldotna line,faults during abnormally high exports,faults during outage of Bernice or Coopergeneration.The cases will be compared in terms of first-swing stability,damping,steady state stability,and voltage stability.Voltage stability will be of particular concern under heavy Kenai import conditions (Bradley Lake units off-line). 6 Equipment availability/feasibility:Visit manufacturers to confirm necessaryequipmentisavailable,visit other utilities with series capacitor and SVS experience. Based on above studies,select the SVS-SC scheme or the Two-SVS scheme. Power Technologies,Inc.Page 7 It may be noted that SSO problems are not addressed in Subtask A.SSO problems aresolvablethroughSVScontroldesignandthusarenotconsideredtobeafatalflaw.Also,eliminating SVS(s)from the solution to stability problems would be untenable at this point in time. SubtaskBstudies -to provide technical information for SVS and SC specifications andfinaldesigndataforothersystemadditionsorchangestoprepareforBradleyLake operation.These studies will focus on either an SVS-SC scheme,or a Two-SVS scheme as determined in Subtask A. The first step in Subtask B will be to prepare a complete computer model of the system with Kenai plant models based on the tests conducted in Task 2.Prepare a detailed model of the Bradley Plant from Fuji data,Woodward governor data and tests.Update the 1991 network model with any recent changes in plans (start with the network model prepared for the load shedding study). '1 Short-circuit study:To assess duty on all existing Kenai equipment and the need for upgrading or replacement,thermal duty on SC bypassing equipment (if SC are included in chosen scheme),and fault levels at SVS locations.Both positive and negative sequence network models will be prepared.Balanced and unbalanced fault cases will be run for all bus and line faults that will determine equipment ratings | or impose severe duty on series capacitors.Both near term and possible futurefaultlevelincreaseswillbeconsidered. The short-circuit study results will be used to check momentary and interrupting capability of Kenai 115 kV switchgear.The results may also be used by HEA or CEA to check 69 kV and lower voltage equipment ratings. 2 SSR Studies:Complete the SSR studies begun in Subtask A;if an SVS-SC scheme is chosen and,if mitigating measures are needed to ensure freedom from SSRproblems.The remedial measures to reduce risk of SSR listed in item 2 of SubtaskAwillbeconsideredinmoredetail.The one or ones that ensure freedom from SSR in a most cost-effective way will be defined.Detailed requirements for the measures will be described. 3 SSO Studies:The potential for SSO associated with the SVS,and possiblyaggravatedbySC,will be investigated.If SSO is a problem,SVS control modifications or filtering to avoid problems will be defined and demonstrated (manufacturers will be asked to prove their solutions to SSO,or show that SSO is not a problem with their SVS or SVS control design). 4 Optimum SVS and SC:Stability studies will be done to determine the optimumlocationandratingsofSVS(s)and SCs,within any limitations set by the SSO andSSRstudies.Specifically,if the locations and ratings outlined in earlier studies cannot be used,but other arrangements are possible,revised ratings and locations 6 Power Technologies,Inc.Page 8 to meet stability requirements will be defined.To the extent allowed by technicalconsiderations,the least costly SVS-SC or Two-SVS scheme that will meet SSO,SSR,and stability requirements will be defined.The SVS and SC complement will be tested against all stability criteria established in earlier studies,including 115 kV unsuccessful reclosing,multi-shot unsuccessful 69 kV reclosing,and threc-phase faults on the Bradley-Soldotna line (including accompanying loss of Kenai load due to voltage dip),Other line faults include the Soldotna to Diamond Ridge line which drops the Ski Hill,Anchor Point,and Kasilof substations and their load.The stability criteria will include first-swing stability,damping,steady state stability, and voltage stability. 5 TRV study:The TRV work begun in Subtask A will be completed.The work in Subtask A will indicate the nature of the TRV problem (if any),and its cost.In this study the work will be completed to the point of specifying equipmentmodificationsorchangesnecessarytoavoidTRVproblems.Solutions may include opening resistors in circuit breakers or circuit breaker replacement.(*) 6 Series capacitor MOV:The studies in Subtask A will shown whether or not bypassing is needed,and its approximate cost.In this study,the detailed requirements will be defined,including MOV thermal capability,MOV protection level,etc.Though MOV may not be needed in 1991,it is likely to be needed at some point in the future if additional generation is placed in the Kenai region. Therefore,the SC will be designed to allow for future fault levels and future MOV protection even if no MOV is required in the initial installation. The MOV requirements will be determined from short-circuit studies (see above)and time-simulations (stability cases)that show actual fault currents over time.Data will be collected on Kenai 115 kV protection to establish fault durations that will be imposed on the series capacitors.The fault duration is as important as the faultlevelindefiningtheneedforbypassingequipment.(*) 7 Voltage control:Dynamic and steady state control of backswing overvoltages,control of load rejection overvoltages,dynamic overvoltages at Soldotna,will be examined.The studies will ensure that substation and line termination arrangements do not encourage overvoltages,and that SVS controls,shunt capacitorbankcontrols,and equipment ratings (e.g.,SVS reactive rating)and placement willreduceriskofequipmentorloaddamagefromfundamentalfrequencyovervoltages. 8 SVS control requirements:Studies will be done to define SVS stabilizer,reactivecontroller,and voltage controller requirements,and necessary adjustment ranges.The facilities for remote control and for special control to ensure that damping isgivenpriorityoverfirst-swing stability will be identified. Power Technologies,Ine.Page 9 10 11 12 18 Protection:Study to assesa and solve potential problems with nuisance operation of existing protection.Address: °115 kV and 69 kV distance protection, )existing out-of-step relays on lines and generators, fr)loss-of-excitation,under and overfrequency,external fault backup,and similar relays on generators. Define need for out-of-step trip and block protection,and blinders,on all 69 and 115 kV lines between Bradley and University.The study will address both marginally stable and unstable disturbances,under both normal and emergency operatingconditions.Consideration will be given to equipment damage that can result frominstabilityandcollapse. Brake and deflector trigger points:Undervoltage trigger relay type,location,and settings,remote triggering from line relays north of Soldotna,deflector run-in rate setting,brake removal algorithm,and similar parameters will be developed.The brake and deflector controls will be optimized for both first-swing stability (especially for fault and trip of the Bradley Lake to Soldotna line)and for loss of the Kenai to Anchorage tie.Loss of the Kenai-Anchorage tie will be examined under a range of export levels,Kenai generating patterns,and Kenai load levels. Loss of the tie due to instability shall also be considered. SVS loss evaluation:Develop penalty structure for inclusion in specifications,and for use in comparing manufacturers proposals.SVS losses will be a significant consideration in comparing options,and it is only fair to let the candidates know the analysis that will be used.The loss-penalty structure will include an annual operating pattern (a load-duration curve where the load is SVS loading in MVAR), a capacity charge curve,and an energy charge curve.If the capacity and energycurvesareessentiallyflat,they will be simply two numbers.If the capacity andenergychargesvarysignificantlywithseason,and we can develop two or more sets of SVS load-duration curves based on seasons,this will be done to refine the loss-penalty analysis. Harmonics:Develop criteria for SVS specifications and prepare system harmonic characteristics to be provided to manufacturers in specifications.Run harmonic scans On various normal and credible abnormal operating conditions,and preparepolarorbodeimpedanceplots.Outline simulator and field tests that will be used to assess harmonic levels before and after installation of the SVS. Stability studies:Summary stability studies to demonstrate that the system definedindetailthroughtheabovetaskscontinuestomeetallstabilitycriteria.ExamineseverefaultsnearBradley,as well as limiting faults elsewhere,including 69 and115kVreclosing. Power Technologies,Inc.Page 10 14 15 16 Islanded operation:Stability studies to show the islanded operation that will resultfromtheSVS,SC,and control studies listed above.Revise any conclusions orresultsderivedaboveasnecessarytoensuresatisfactoryinterconnectedand islanded operation,and identify and refine any additional requirements such as unittrippingthatmaybenecessarytoensurereliableislandedoperation.EspeciallyidentifysignalsthatmustbesentfromQuartzCreektoBradleytoapplythebrake, trip a Bradley unit,or reduce the governor speed reference.Coordinate with similar controls to Soldotna,Bernice,and Cooper. New 138 kV:Analyze impact of a new 188 or 115 kV line from Soldotna to University on the SVS and SC requirements defined in above studies.Purpose is to ensure that the system is designed to take maximum advantage of a new line. A new line will not degrade stability,but if it is to contribute to stability,or allow increased export,some adjustment to shunt (SVS)or series compensation may berequired.Any future changes to SVS or SC equipment that may be necessary when a second line ig installed should be clearly outlined in the initial purchasespecificationstoeasethefutureupgrade.For instance,if an increase in the SVS size may someday be necessary,manufacturers will be instructed to provide space and contro!facilities for those increases. Complete operating plan:A complete operating plan will be prepared.It will address all normal and credible emergency operating conditions in the 1991-1992period.The plan will outline the practices that operators should follow to ensure minimum impact of disturbances,and quickly restore the system when separationorblackoutdoesoccur.The study will address AVR settings at Bernice,Soldotna (generator and SVS),Cooper,and Bradley,reactive loadings,braking resistor arming points,maximum safe export under various operating conditions,ete. The operating plan will cover a range of probable generation dispatch scenarios, Kenai load levels,and Kenai export levels.Abnormal (contingency)and emergency(high export)conditions will also be considered.The operating plan will address: 3)SVS operation:voltage settings and normal reactive loading as a function of system state (Kenai generation dispatch,Kenai load,and export level,). re)Operator responsibility for setting braking resistor controls,deflector run-in rate,enabling or disabling transfer trip from Quartz to Bradley,etc. )Bradley braking resistor and deflector control settings to best improvestabilityandreducefrequencyexcursionsduringandfollowingdisturbancessuchaslossoftheKenai-Anchorage tie. re)Reactive power levels and voltage regulator settings at Bernice,Soldotna,Bradley Lake,and cooper (which must be coordinated with the SVS operatingstate). Power Technologies,Inc.Page 11 Budget: The Task 3 studies are estimated to cost $265,740. Status: The Task 8 studies have not yet been authorized. *These studies required only if the SVS-SC scheme is chosen, Power Technologies,Inc.Page 12 Schedule: Engineers: Objective: Not yet established. Harrison Clark,John Doudna,Steve Lambert,Lou Hannett To assist in preparation of requests for qualifications and technical and cost proposals from SVS and SC manufacturers,and to provide engineering associated with selecting a manufacturer,proving manufacturers designs,and conducting field tests. The engineering work will include five areas as detailed below: °ions;The results of studies conducted in Task 3 will be extracted and assembled in a request for proposal format for use by the engineer (SWEC)in assembling a turnkey supply RFP.The material that will be prepared includes: "machine/network data (fundamental frequency and harmonic), --background on the system stability and voltage control requirements, and on planned operation of the system, -harmonic and contro]stability criteria and requirements,SSR and §SO criteria and control requirements, "voltage,current,short-circuit,reactive power ratings and withstand requirements, "control response requirements,adjustment ranges,remote control,etc., and "design verification simulator tests,acceptance tests and commissioning tests. This and similar requirements will be developed for the SVSs,SCs, Stabilizers,and Monitor/brake controllers. Performance simulations;The manufacturers proposed SVS designs will beinspectedfordifferencesthatcouldaffectsystemperformance.Observed differences will be analyzed through comparative simulations of worst-case Power Technologies,Inc.Page 13 disturbances such as fault and trip of the Bradley to Soldotna line,fault and reclose on 115 and 69 kV lines,and loss of the Kenai-Anchorage tie. )Design verification studies;Digital and simulator studies will be run toassesstheperformanceofcontrolequipmentbeforeitisauthorizedfor shipment to Alaska and installation.The studies will include: Digital simulation of harmonic performance of proposed filter banks. Harmonic scans will be run with and without the proposed filter banks to show that system harmonic penetration is limited,and filter resonance is not a problem (a filter at one frequency can cause a troublesome parallel resonance at a lower frequency). The digital model used for these studies includes the complete network and all generators,but is especially formulated to calculate system response to a wide range of frequencies as can be generated by SVS equipment. Simulator studies of SVS control performance to show that SSR and SSO are controlled,the controls are stable in the presence ofharmonics,and that the controls respond properly under a range of credible switching,unbalance,fault and load rejection conditions.Forthesestudies,the control equipment that will ultimately be installed in Alaska will be shipped to a simulator facility,connected to generic SVS components (thyristors,capacitors,reactors),and interfaced with a system mode!for the tests. The simulator models a small portion of the network in great detail, with an equivalent model beyond that portion.It faithfully reproduces the network high frequency characteristics (above 60 Hz). Digital simulation of fundamental frequency performance.If the simulator studies or the proposed control characteristics are unusual or significantly different from expectations in any way that might affect fundamental frequency performance,the controls will be tested on the detailed system model in PSS/E.Most such differences will be recognized and treated in the performance simulations (see next above bullet).However,simulator studies may reveal control characteristics that should be examined. The fundamental frequency simulations conducted with PSS/E utilize a detailed network and machine model that is accurate up to about10Hz.It thus faithfully demonstrates system response to powerswingsandoscillationsinthe.2 to 1.5 Hz region caused by faults andlinetrips. Power Technologies,Inc.Page 14 °Bid Support:Other engineering tasks that arise during bid evaluation andcontractnegotiationwillbehandledonanas-needed basis. r)Field Support;Engineering tasks that arise during installation,testing,andstart-up will be handled on an as-needed basis.An example would be reviewofcommissioningtestresults. Criteria:N/A Budget:$114,800 Status:Not yet started. Power Technologies,Inc.Page 15 Schedule:x Engineers:x Objective:«x Criteria:x Budget:x Status:x PROPOSED SVS/SC PROCUREMENT PROCESS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY Task Months Issue supplier prequalification 0 Receive prequalification data (30 days)1 Send out draft of technical RFP to 2 prequalified suppliers Comments on draft RFP due (30 days)3 Issue technical RFP (Coincides with 4 draft of study results) Technical proposals due (30 days)5 Evaluate and negotiate proposals (45 days)6. Price bids due (15 days)7 Notice of award (14 days)7. Notice to proceed (14 days)8 SVS inservice date (fastest 12 months)20 (average 15 months)23 (longer 18 months)26 &A.G EN DA Technical Coordination Subcommittee Bradley Lake Hydroelectric Project October 5,1989 9:00 a.m. at Alaska Energy Authority I.Adoption of Prior Meeting Minutes II.Approval/Modification of Agenda III.Old Business A.SCADA DECNET Interface B.Surge Tank Investigation IV.New Business A.Governor Factory Test B.Stability Studies 1.PTI Study Plan 2.Kenai Unit Test Results 3.SVS/SC Procurement Method 4.Schedule V.Adjournment SUBTASK-A SSR Studies SSP Solutions SC Bypassing TRV Duty On Breakers Robustness of Solution Equipment Availability/ Feasibility SUBTASK-B Short-Circuit Studies SSR Studies SSO Studies Optimum SVS &SC TRV Study Series Cap MOV Voltage Control SVS Control Requirements Protection Brake & Deflector Triggering BRIEF STATUSOFBRADLEYSTUDYEFFORTS TASK3 Held up pending receipt of Kenai machine shaft torsional data. Same as above. Same as above. HELD UP.System configuration (i.e.,series caps or two SVSs)must be determined before this study can be done. Same as above. Same as above.(Though some work on this task has been done on this task,further work may not be essential). Short circuit model established for Kenai.Some short circuit work done.Final short-circuit work presently in progress. Same as for Subtask A. Same as for Subtask A. Same as for Subtask A. Same as for Subtask A. Same as for Subtask A. Should know final SVS configuration but could proceed sooner. Same as above. Same as above. Almost complete.Presently verifying effect of new detailed Bradley model on recommendations. SVS Loss Evaluation Harmonics Stability Studies Islanded Operations New 138kV Line Operating Plan Bradley Model Development Technical Specification Essentially complete.Billed as part of Task 4.This "item may require additional work of two SVS scheme is utilized. Need to know final system configuration before this work is feasible. Partially done as part of brake &deflector triggering work.Final studies not feasible until final system configuration is known. Ready to start.Detailed Bradley model needed for this study is now available. Not yet done.Need to know final system configuration. Not yet done.This will be the last item. Complete except for 3rd mode.The model can represent the "needle set by power"type of 3rd mode operation. Further modeling work will be required to model "needle set by deflector"type of operation when data becomes available. TASK4 Second draft of spec complete and sent to SWEC.Remaining work under Task 4 can occur only after series capacitoruseisdefinedandSVSarebid. WOTED C.MCGEE WY22"BY FACSIMILE TRANSMISSION +CRM WOODWARD GOVERNOR COMPANY HYDRAULIC TURGINE CONTROLS NIVIS)08 230)COUNTRY Cuue ORIVE P.0.BOY 247 STEVENS POINT,W2 $4631-0287 TELEPHONE:725/344-2380 TELEX:671-2868 TELEFAX:713/344-0053 TELEFAX VERIFICATION 715/344-2350 exT.115 Date:rosy.22,19 £49 ; Ta:-Stins and bweester - Attention:-Jonn=-Yale . Reference:eplley leks-FAX No.:(303)741-7679 From:_lg uma No.of pages,incTuding cover sheet:3 '.Cohn,Atterludl are th,torquw WS.Spurl Curves Cor Eradley LaksOtWZ%mcd WOR Loed.For Lun purporto,Ue che va hoped turqu GQurve Sho:move up an squeal Adntenu across te At W%,Local,the clevelogecl lorgue Curve wrtt aedth,Wed torqus eurvucg al Ong bie,3i0 re The norsaud«2 Iud rpm,evfora ot parmch Geol,ths Oper-" Loop \blocked )Sueur wo uxcleblu NG: i ya the IO?phew lag of th plant.Fanatic a TetyheGonctut.;wt Out ad anived ot th,yar itrdTORQUEPTTtTTiLeeeae{Jftffftd) 0peril Spee 100 PERCENT LOAD TORQUE73 PERCENT LOAD 3 <I Se :"RY S we we i se Loab a ae 'TORQUE |/ .ee ie ae-K.,---= a ToRaue SA ™ ss 2 yy I it ut ]ee ee |i {ef jt {ft } 240 260 280 300 320 340 360 380 400 SPEED CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska June 1,1989 TO:David H.Highers,General Manager VIA:Eugene N.Bjornstad,Executive Manager, Operating Divisions df .Michael E.Massin,Director W)aonEngineeringDivision FROM:David W.Burlingame,Manager UgFacilitiesEngineering SUBJECT:Bradley Lake TCC Meeting -June 1,1989 The following is a synopsis of the above referenced TCC meeting: SCADA:Landis &Gyr is the apparent low bidder for the plant SCADA system.The system will be purchased with a DEC-NET port to allow the plant to put information directly into the DEC-NET system without having to go through Chugach Electric Association,Inc.(Chugach).This was done primarily at Golden Valley Electric Association's (GVEA) request.The bid also included a price to emulate the Chugach SCADA protocol in the plant SCADA system as opposed to Chugach supplying an RTU for use in controlling the plant.This would mean the dispatching of the plant would go through the plant SCADA system as opposed to a direct connected RTU.APA also stated that Homer Electric Association,Inc.(Homer)would be responsible for the maintenance of this RTU as they are the plant operators. Homer stated their SCADA system would not be on-line in time for Bradley Lake,therefore Chugach will be required to install an RTU at Homer's Diamond Ridge station. APA Transmission Line -The hearing for the award of the transmission line from Bradley Lake to Bradley junction is scheduled for June 5,1989.APA expects a ruling by June 26,1989.If the ruling is to award the project to either Newbery or Western,APA will immediately issue the Notice to Proceed.If the ruling determines that neither of the two lowest bidders are responsive,then APA plans on rebidding the project. Dave Highers -2-June 1,1989 Bradley/TCC Mtg Homer Transmission Line -The estimate for Force Account construction has been prepared by Homer and is being forwarded to Gilbert Commonwealth for their review and approval.Pending their approval,Homer plans to forward the estimate to REA for their review June 9,1989.One interesting item is the pole delivery,Homer stated that if a pole order was not placed by mid-late June,the project would miss the 1989-1990 winter construction season.Homer also stated they would not order the poles without REA approval of the project.Homer estimates the order to be approximately $600,000. PTI Stability Studies -PTI has submitted an estimate for the studies required to finalize the design and specifications for the non-intertie stability aids.This work is estimated to cost approximately $600,000 and take 3-4 months to complete.Stone &Webster prepared a scope of services for the utilities review outlining the work to be done.Comments are due by June 16,1989.APA stated that PTI is now a subcontracter to Stone &Webster and that all future costs for stability studies will be borne by the project.The utilities requested that Stone &Webster review and approve PTI's work and stand behind their recommendations.The primary motive behind this is the continuing struggle with General Electric/Gilbert on the Intertie equipment. It was also recommended and approved by APA that at least two utility representatives should review and approve any directives or changes to the SVS equipment manufacturers prior to implementation. Bradley Lake Governor Design -Woodward is having difficulty designing a governor to meet the specifications and IEEE Standards for stability.In sense this is purely a theoretical deficiency which only exists when only one unit is running isolated on the Kenai at or below 733 of its capacity.Homer and Chugach were requested to provide a representative load information to be used in the governor modelling. PMC Items -The following items may more appropriatelybelonginthePMCarena: Dave Highers -3-June 1,1989 Bradley/TCcC Mtg O&M -APA has indicated that all equipment installed under the project umbrella would be the responsibility of Homer to Maintain and Operate.This presumably would include any SVS equipment at Soldotna station.We should clarify that Chugach leases the Soldotna station from Homer and to be consistent with present policy and to ensure the integrity of the Chugach transmission system,we would expect to provide O&M at Soldotna. We should also clarify the status of the Bradley Lake Dispatch RTU O&M and its direct connection to the Chugach system as opposed to through the plant SCADA system. DWB/pv DWB1-69 File 411 cc:T.Lovas (file 4/2 STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREET'ENGLEWOOD,COLORADO 80111 ADDRESS ALL CORRESPONDENCE TO P.O.BOX 5406,DENVER,COLORADO 80217-5406 W.U.TWX:910 935-0105 TELEPHONE:303 741-7700 FAX:303-741-7670 W.U.TELEX:45-4401 RCA TELEX:289251 303-741-7671 BOSTON NEW YORK CHATTANOOGA PORTLANO ME CMERRY HILL NJ PORTLAND OR CHICAGO RICHLAND WA DALLAS RICMMOND VA SENVER SAN FRANCISCO FY LAUDERDALE TAMPA HOUSTON WASHINGTON OC Mr.David Burlingame January 11,1990 Chugach Electric Association P.O.Box 196300 Anchorage,Alaska 99519-6300 RECEIVED BYTECHNICALCOORDINATIONSUBCOMMITTEEMEETING JANUARY 17,1990 f BRADLEY LAKE HYDROELECTRIC PROJECT JAN 1%1990 ALASKA ENERGY AUTHORITY .ExGinccrincTTTORRONT On behalf of the Alaska Energy Authority,enclosed you will find documents for the next meeting of the Technical Coordination Subcommittee.Please note that the meeting will be held at the offices of Anchorage Municipal Light &Power,1200 East lst.Ave,on Wednesday January 17,1990 beginning at 9:00 AM.Enclosed are the following materials for your use in preparation for the meeting. Agenda Minutes of December 13,1989 TCS Meeting Load Acceptance Analysis -Final Draft Draft Kenai Generator Test Report Revised Schedule for Stability Studies/Procurement Draft Specification for Brake Resistor Cost Estimate for Additional Railbelt Generator Testing HEA letter of January 3,1990 At the meeting we will distribute a draft description for the proposed third operating mode for the Woodward Governors. aleodore”Critikos Project Manager TC/JBY/CM Enclosures cc:Mr.David Highers Chugach Electric Association 'xau >STONE &WEBSTER -:ws IIt. Iv. AGENDA Technical Coordination Subcommittee Meeting Bradley Lake Hydroelectric Project Held at the offices of Anchorage Municipal Light &Power 1200 East lst Avenue January 17,1990 -93:00 a.m. Approval of December 13,1989 Meeting Minutes Approval/Modification of Agenda Old Business A. B. Load Acceptance Analysis (Surge Tank Study) Kenai Generator Test Report SCADA DECnet Interface Status Report CEA/DIVCOM Microwave Link -Cost Estimate Governor-Proposed 3rd Mode of Operation New Business Revised Schedule for Stability Studies and SVS Procurement Brake Resistor Procurement -Draft Specification Railbelt Generator Testing -Cost Estimate Project Test Period Adjournment BRADLEY LAKE PROJECT TECHNICAL COORDINATION SUBCOMMITTEE (TCS) MINUTES OF DECEMBER 13,1989 MEETING The meeting came to order at 8:30 a.m.in the Anchorage offices of the Alaska EnergyAuthority.In attendance were: John Yale SWEC .Myles C.Yerkes MEA Steven Haagenson GVEA David BurlingameR.Olson M.Aslam CEA CEA ML&P AEA AEA Sam Matthews HEA ML&P CEA AEA CEA SWEC Minutes of the previous October 5,1989 TCS meetings were approved as drafted. The sed was €ded to include,under New Business a posedcommunicationromtheCommitteetoDecisionFocus,INC.(DFT),and review of theupdatedscheduleofrequiredsystemstabilityequipment. First,the Committees discussed the latest draft of the Kenai Export Study (dated12/4/89)from Power Technologies,Inc.Following substantial discussion the Committeeunanimouslyrecommendedthefollowing: 1 =Modify secure and emergency definitions,Proposed wording wastentativelyapproved,to be drafted by Stone &Webster.5 2.Modify the Kenai Export Limit matrix (Page 6)to reflect correct definitions ofsecureandemergencytransport. 3.Provide clear,concise summary of the prudent,realistic export limits. 4.Delay an additional work on this until phase three of the on ing Kenai stabilistudiasazocompletedbyPTI(estimated JuneorJuly,1990).pome enki ¥ Next,Norm Bishop and John Yale of SWEC presentedthedraft rt on "LoadAcceptanceAnalyns”(dated December,1985).This report summarizes the stability and BRADLEY LAKE PROJECTTECHNICALCOORDINATION SUBCOMMITTEEMINUTESOFDECEMBER13,1989 MEETING Page 2 spinning reserve benefits of improved Bradley Lake generator/turbine governorresponsetimewhichcanbeachievedbyconstructinghydraulcsurgevans.ThisengineeringanalysisprovidedthefirstindicationoftheabilityofBradleyLaketoprovidesystemspinningreserves.In general,the Committee tended to accept the studytechnicalanalysisandconclusions.Adding a surge tank at a cost of approximately $15.2millionwillimproveprojectoperation,however,it will contribute very little towardsprovidingspinningreserves.Following considerable discussion,the Comumittes electedtodelayactionuntilthereportisfinal. Next the Committee approved the prior recommendations of the SCADAsubcommittee.Items approved were: 1,AEA will negotiate an agreement with the SCADA vendor to provide "DECNET”software which is completely compatible with the existing utility systems.TheagreementandpriceproposalwilbepresentedlaterforapprovalbytheCommittee. 2.Approved activation of Homer area microwave communications related to theprojectlongtermrequirementsplan. 3.Approved a request from CEA to provide a new direct microwavecommunicationslinktotheCEAAnchorageheadquarters.CEA,by letter of12/11/89,offered to fund 50%of this cost,r,the Committee considered allcostsarearequirementofBradleyLakewhichshouldbefullyreimbursed,AEAwillproceedwithconstructionofthislink.Reimbursement of CEA costs will bedirectedtotheProjectManagementCommittee(PMC)for formal approval. Next Mr.-Yerkes presented a proposed letter to DFI regarding intertie studoneThe'etter was vhanimously approved with minor correctionsabstainin° John Yale discussed the possibility of modifying the turbine governor control softwaretoprovideimprovedresponseandstability.After considerable discussion,theCommitteeunanimouslyrecommendedthattheWoodwardGuvernorcontrolsoftwarebemodifiedtoprovidethefollowing: 1 Automatic switching to six nozzle operation by manual switching or by reaching ableunderfrequencysett.will remainonsixpatmanual]commanded 'to reunne 8efficient operation.Operation will bealarmedbySCADAtotheprojectoperatorsanddispatchers. 2.Automatic switching to water wasting deflector control by manual switching or byreachingaprogrammableunderfrequencysetpoint.The needles in thisoperationalmodewillopentoaprogrammablesetpointandremainatthispointusingthedeflectorstogovernthemachinespeed.Once in this mode,manualswitchingshallberequiredtoresumenoperation.Operation in this modewillbeviaAtotheoperatorsdispatchers. .( BRADLEY LAKE PROJELT TECHNICAL COORDINATION SUBCOMMITTEE MINUTES OF DECEMBER 13,1989 MEETING Page 3 Under SVS procurement,John Yale advised that under the most optimisticarcumstances,delivery of the SVS system could occur by February 5,. A realistic schedule would require an additional six months of time. The next Committees meeting will be scheduled by Dave Eberle prior to the scheduledJanuary20,1990 Project PMC meeting. The meeting adjourned at approximately 6:00 p.m. ; SUBMITTED: Cc.VICE-CHAIR APPROVED: DAVID EBERLE,CHAIR MY:BB ) 302A.900102.363 - SECTION 5.17LOADBANKRESISTORS Part Title 1.0 SCOPE 1.1 Extent of Work 1.1.1 Reference Documents 1.1.2 Related Work 1.1.3 Reference Drawings 2.0 TECHNICAL REQUIREMENTS 2.1 General 2.2 Equipment Ratings 2.2.1 Power Rating 2.2.2 Rated Nominal and Maximum Voltage 2.2.3 Insulation 2.2.4 Rated Ohmic Value of Each Phase 2.2.5 Temperature Limits and Duty Cycles 2.2.6 Cooling .2.3 Material and Enclosure 2.4 Terminals and Termination Cabinet 2.5 Construction 2.6 Seismic Requirements 2.7 Arrangement of Equipment 2.8 Accessories to be Provided 2.9 Grounding 2.10 Welding 2.11 Cleaning and Painting 2.12 Prohibited Materials 2.13 Tools 2.14 Operating,Installation and Maintenance Manuals 2.15 Spare Parts QUALITY ASSURANCE/QUALITY CONTROL TESTS Tests General Factory Tests Inspections Preparation for Shipment Provision for Storage Guarantee SubmittalsWWWwWwWwWwWWwNOUEPWNHRHO 00968 .wpf FNNeeSENNDNDN&WWWWwWWwWwwwWwOoooooCOOO ) SECTION 5.17 LOAD BANKRESISTORS 1.0 SCOPE This specification defines the technical and quality assurance requirements for furnishing,delivery,installation and testing of load bank resistors and their appurtenances. The Contractor shall use this document to gain familiarity with the technical requirements of the equipment being purchased.The Contractor shall combine their manufacturing experience and the technical requirements of this specification to prepare and submit a comprehensive proposal depicting the design,manufacturing and testing approach in meeting the objective of thisspecification.All requested exceptions and deviations from the requirements of this specification shall fully be explained and if applicable,a proposed alternative shall be presented. 1.1 Exte Wo .Work to be performed under this section,includes but is not limited to, providing the following: Two load bank resistors 15.0 Kv feeder bus Four 15.0 Kv circuit breakers Accessories and spare parts Special tools Drawings and data Operating,installation and maintenance manuals Testing of the load bank resistors and circuit breakers Technical support for installation and field testingWONKNWWHDHeeeee*.°.e1.1.1 Reference Documents If there is,or seems to be,a conflict between this specification and a referenced document,the matter shall be referred to the construction manager. If the manufacturer of the above equipment is located in a country where the referenced standards are not in effect,the buyer may grant permission to the manufacturer to comply with the applicable standards of that particular country only after a complete and satisfactory review process of the foreign standards. Otherwise,the work performed under this section shall be in conformance with all applicable American codes and standards,but not limited to the ones listed below. American National Standards Institute (ANSI) ANSI €57.13 1978 Requirements for Instrument Transformers R1987 00968 .wpf 1 { ANSI 255.1 1967 Gray Finishes for Industrial Apparatus and R1973 Equipment 1.1.2 Related Work The following sections relate to the work described herein: Instructions to BiddersSection1.2 Section 1.4 Bid Forms Section 2.3 Measure and Payments Section 2.6 General Seismic Requirements Section 2.7 General Quality Assurance/Quality Control Requirements Section 2.8 Contractor Submittal Requirements Section 2.10 Environmental Compliance Section 2.13 General Welding Requirements Section 2.14 General Painting Requirements Section 2.17 General Shipping,Receiving and Storage Requirements Section 2.18 Installation of Equipment Section 2.20 Start-up,Testing,and Commissioning Section 5.4 15.0 Kv Switchgear Assemblies Section 5.5 15.0 Kv Bus .Section 5.12 Grounding Systems Section 5.14 Installation of Electrical Equipment and Materials 1.1.3 Reference Drawings The following drawings detail the work to be performed under this section: aw [e]Title 15800-FC-212 Series General Arrangement Series 15800-FE-1 Series One Line Diagrams 15800-FE-21 Series Three Line Diagrams 15800-FE-29 Series 15.0 Kv Bus Duct Arrangement Series 15800-FE-33 Series Grounding Series The following drawings were specifically revised or prepared to delineate the preliminary location of the equipment: Drawing No,itle 15800-FE-1A Operational One-Line Diagram SK-19239-E-1 Proposed Bus Ducts and Load Bank Resistors Arrangement SK-19239-E-2 Proposed Bus Ducts and Load Bank Resistors Arrangement 00968 .wpf 2 2.0 TECHNICAL REOUTREMENTS 2.1 General The load bank resistors provide two functions for the Bradley Lake Station and Kenai Peninsula Power Systen. 1.Swing stability is improved when the load banks are switched on following a fault. 2.Overspeed following separation from the main (Anchorage)system is reduced by switching the load banks on following separation. The load bank resistors impose a temporary load on the generators reducing overspeed. 2.2 Equipment Ratings The two load banks shall be identical in all respects and each shall be three phase,WYE-connected with the following specifications. -2.2.1 Power Rating (Rated Wattage) The ratings given are preliminary.It is expected that the final rating willbethosegiven+10%. Each three-phase load bank is to have a nominal rating of 25Mw.Individual phase units are to be rated 8.33 Mw.The load banks are to average 25Mw over the first one second of operation when energized at an ambient temperature of 20°C at rated voltage. The power drawn by the load bank shall not fall more than 20%(to 20Mw three phase or 6.66Mw per phase)at the end of 2 second application when the load bank is energized at a 20°C ambient at rated voltage. 2.2.2 Rated Nominal and Maximum Voltage The load banks shall be constructed and insulated for a nominal line-to-line or phase-to-phase voltage of 13,800 volts.The load banks shall be capable of withstanding a maximum voltage of 15,180 volts for full 2 seconds rated operating time with no significant loss of life. 2.2.3 Insulation The load banks,enclosure,and supporting structure shall be designed for a BIL of 90 Kv. 2.2.4 Rated Ohmic Value of Each Phase The resistive ohmic value at 20°C,and associated thermal design,shall achieve the power ratings listed above. 00968 .wpf 3 ( The inductive reactance of the complete load bank at 60 Hz shall be minimized and shall be taken into account in designing for specified resistance and wattage ratings. The tolerance in phase module resistance value shall be established by the Contractor so that power absorption at rated voltage will be no more than -0, +5%relative to the specified rated wattage. Resistance at 20°C of parallel paths within any phase shall differ no more than 5%. Resistance at 20°C of the resistor element attaining the highest temperature by virtue of its position in the load bank shall not increase more than 5%over 50 years of duty outlined in the following section. 2.2.5 Temperature Limits and Duty Cycles The temperature of resistive elements shall not exceed the safe value for the resistive material,supports,and insulation under the duty cycle outlined below. Design lifetime shall be 50 years at the frequency of use listed below. -The load banks shall achieve a 50 year life.All resistor elements and insulators shall remain serviceable at the end of 50 years,though complete replacement may be warranted to ensure continued reliability. The lifetime and temperature requirements shall be met under the following duty cycles: °thirty 1 second applications per year with no more than two such applications occurring within any 24 hour period,and no less than 1 minute between any two successive applications. °twelve 2 second applications per year with no more than two such applications occurring within any 24 hour period,and no less than 5 minutes between any two successive applications. 2.2.6 Cooljin The load bank resistors shall be naturally (convectively)cooled and suitable for indoor installation.Ventilation ports in the enclosure shall accommodate the specified duty cycle in a 20°C environment. Cooling vents should be designed so as to minimize dust accumulation on resistor elements and insulators.Provision shall be provided for dust removal without significant disassembly of the load bank. 2.3 Material _and Enclosure The load banks shall be of cast grid type or of other materials such as stainless steel which will meet the duty and life requirements set forth in this document. 00968 .wpf 4 ( The resistor elements shall be grouped into units and housed in suitable metal enclosures. The enclosures shall protect the resistor elements from normal traffic and equipment that may be used in the vicinity of the associated switchgear.The enclosures shall also protect workers from the heat generated during load bank application.The enclosures shall contain any fragments that may be generated upon failure of resistor element,and shall prevent massive scattering of material from the load bank upon occurrence of a normally cleared short-circuit within the load bank enclosure. 2.4 TerminalsandTerminationCabinet Terminating cabinets shall be weatherproof,fabricated from steel plate of sufficient thickness to prevent warping or buckling,and shall have drip-proof hood.Terminal blocks shall be General Electric Type EB-25 or equal.They shall be located a minimum of 10 inches from the base of the termination cabinet.Each terminal shall be numbered or marked in a clear,easy-to-read manner with labels which refer to the designations used on wiring diagrams.The terminal arrangement shall be subject to approval.Spare marking strips shall be furnished with each block.At least 20 percent spare terminals shall be .provided.Parallel rows of terminal blocks shall be spéced a minimum of 5 inches on center.Terminal blocks for current and potential transformer circuits and for 120 Vac and 125 Vde power supply circuits shall be separate from each other and from blocks for control wiring.They shall be of a type similar to control wiring blocks but shall be capable of accepting a No.6 AWG maximum wire size. Terminal blocks for current transformer circuits shall be the shorting type. 2.5 Construction The construction shall facilitate access to each resistor element.The elementsshallberemovableforrepairorreplacementwithoutcompletedisassemblyof phase modules. 2.6 Seismic Requirements The load bank resistors shall be seismically qualified to be operational after the Design Basis Event (DBE)in accordance with Section 2.6,General Seismic Requirements,by any of the methods specified therein.A Certificate of Compliance is required. Equipment anchorage shall be designed by the Contractor.Equipment shall be secured to prevent overturning and sliding.The floor slab where the resistors are to be located has been placed.Drilled-in concrete anchors shall be the preferred method of securing the equipment.For further information,refer to subsection 2.3.6 of Section 2.6,General Seismic Requirements. 2.7 Arrangement of Equipment The proposed location of the load bank resistors is at elevation 42 foot,column Cl and close to the north wall.15.0 Kv switchgear shall be adjacent to the load 00968 .wpf 5 ( bank resistors.Drawing 15800-FC-212C shows a plan view of this area.Sketches SK-19239-E-1 and SK-19239-E-2 show the suggested cabinet and bus arrangement. 2.8 AccessoriestobeProvided The Contractor shall supply four metal clad circuit breakers as shown on one line diagram 15800-FE-1A in accordance with Section 5.4 of this specification,15.0 Kv switchgear assemblies. Each load bank resistor shall have two breakers connected in series to provide redundancy in load removal.With one of the circuit breakers normally closed, the second breaker will close to add the load bank resistor to the system.The removal of a load bank resistor from the system is accomplished by opening one of the breakers.If this breaker fails to open the second (back-up)breaker must open to disconnect the load bank resistor from the system.An alternator scheme is required to balance each breakers number of operations.For this application, fast acting,vacuum breakers of operating speed of less than 4 cycles are required. The Contractor shall furnish and assemble the 15.0 Kv feeder bus ducts connecting the load bank resistors to the circuit breakers in accordance with Section 5.5 of this specification,15.0 Kv bus.15.0 Kv bus ducts arrangement are shown on sketches 19239-E-1&2. The Contractor shall provide four identical thermal protection systems for the circuit breakers.Each protection system shall prevent load bank temperature from exceeding a safe operating limit which will not cause a loss of life to the equipment.Safety margin of each protection system shall take into account the operating time of the circuit breakers.The sensor for each system shall have similar thermal characteristics to the load bank elements so that temperature reading from each sensor will closely resemble the actual temperature of the load bank elements during multiple operations of the load bank resistors over a period of time. Each thermal protection system shall be supplemented by instantaneous fault overcurrent protection for the load bank resistors and the bus between the circuit breaker and the load banks. Each load bank resistor shall be equipped with a hot spot resistance temperature detector for use with Owner's remote instrumentation. All instrument transformers provided as part of protection system shall meet the requirements of ANSI C57.13 and subsection 2.11 of Section 5.4,15.0 Kv switchgear assemblies. 2.9 Grounding Load bank resistors shall be provided with grounding pads for bolted connections to the station grounding system.Load bank resistors shall have two grounding pads located diagonally opposite on the common base.The location of grounding pads shall include consideration of the effects of enclosure circulating currents.All ground pads shall have two holes on 1 3/4 in.centers,drilled 00968 .wpf 6 and tapped 1/2 in.-13 NC.Grounding pads shall be made of copper-faced steelorstainlesssteelwithoutcopperfacing.The neutral or wye connections shall be made within the load bank enclosure.The neutral of the load bank shall not be grounded. 2.10 Welding All welding shall be in accordance with Section 2.13,General Welding Requirements,of these specifications. 2.11 CleaningandPainting Shop cleaning and painting shall be performed in accordance with Section 2.14, General Painting Requirements of these specifications and ANSI Z55.1,light gray finishes for industrial apparatus and equipment. 2.12 Prohibited Materials Refer to subsection 2.3.21,Hazardous Substances in Section 2.10,Environmental Compliance for a list of prohibited materials. 2.13 Tools The Contractor shall provide all "special tools"for erection/installation, maintenance and operation which are not normally or readily available.The Contractor shall submit a complete list of tools needed for erection/installation,maintenance and operation and a list of special tools which will be provided.Special tools shall become the property of the Owner at the completion of load bank resistors installation. 2.14 era nstallation and Majntenance Manuals Operating,installation and maintenance (O&M)instructions for the load bank resistors and accessories shall be furnished in accordance with the requirements specified in Section 2.8,Contractor Submittal Requirements. 2.15 Spare Parts Contractor shall recommend in his/her tender spare parts to cover a 10 year period of operation.Supplier shall deliver with load bank resistors parts that may be subject to failure but not locally available.Spare parts recommendation list shall cover touch-up paint for possible finish damage during shipment. 3.0 QUA ASSURANCE/QUALITY CONTROL TESTS The specific quality assurance or quality control actions described below are in addition to the requirements of Section 2.7,General Quality Assurance/Quality Control Requirements.The Contractor shall,as part of its QA/QC program, establish and maintain a written quality control program addressing the manufacturing and installation procedures for the equipment specified in this section.Copies of the written document shall be maintained on file and shall be available for use both at the factory and at the construction site. 00968 .wpf 7 3.1 Tests 3.1.1 Gene The Contractor shall be responsible for the performance of tests and maintenance of certified reports of the tests specified below.During tests,data will be logged and reports filed and all control settings and adjustments recorded and retained for future reference.The Contractor shall provide necessary equipment to perform the tests. The Owner reserves the right to witness tests.Where witnessing of tests is required,the Owner shall have reasonable notification of the time and location of the tests. If any requirement of this specification is not met during the tests,the Contractor shall immediately take whatever action is necessary to make the equipment conform to the specification.The Contractor shall be responsible for any retesting to demonstrate compliance with the specification. 3.2 Factory Tests The equipment manufacturer shall perform,in accordance with the relevant standards,a program of standard commercial factory tests on the load bank resistors and accessories. Each load bank resistor shall have the following factory tests performed and results reviewed by the Owner: 1.Full load test 2.Hi-pot test Switchgear shall be tested in accordance with Section 5.4,15.0 Kv Switchgear Assemblies. 3.3 Inspections The following are mandatory hold points for which prior notification is required. 1.Resistor element assembly 2.Factory testing 3.Release for shipment 3.4 Preparation for Shipment Refer to Section 2.17,General Shipping,Receiving and Storage Requirements. The load bank resistors and their accessories shall be shipped in as complete a package as possible.Any disassembled parts shall be clearly marked to facilitate reassembly.Markings shall be made so that they may be removed from the equipment without damaging finish of the equipment. 00968 .wpf 8 { The Contractor shall take all precautionary measures to ensure jobsite arrival of the entire complement of equipment and materials undamaged,and in satisfactory working condition. 3.5 Provisions for Storage The equipment covered by this specification shall be stored at the jobsite or other locations approved by the construction manager,utilizing storage facilities described in Section 2.17,General Shipping,Receiving and Storage Requirements.The Contractor shall submit the manufacturer's recommended storage provisions for each item of equipment or material. The minimum acceptable storage level,as defined by Section 2.17,for equipment and materials of this section are as follows: stem orage ov on Load Bank Resistor Level C 15.0 Kv Bus Duct Level C Circuit Breaker (See Section 5.4) -3.6 Guarantee Both the Contractor and the equipment manufacturer shall guarantee that the load bank resistor and breaker sets shall meet the requirements of this specification. If,at any time during the first 12 months of commercial operation as defined below,the Owner accumulates sufficient evidence to reasonably indicate that the load bank resistors,breakers or any parts thereof is not in accordance with the specifications,the Owner will so notify the Contractor in writing,and the Contractor shall repair or replace the defective components.The cost of removal and reinstallation of the equipment,and any freight charges or service engineering charges shall be at the Contractor's expense.The guarantee for therepairedorreplacedequipmentshallbeextendedforoneyearfromthecompletionofrepairsorreplacement. Commercial operation is defined as the date the installation is complete,the required acceptance tests completed and approved and the equipment accepted by the construction manager. 3.7 Submittals All submittals shall be made in accordance with Section 2.8,Contractor Submittal Requirements,of this specification.The following items shall be submitted: 1.Catalog and technical data for the load bank resistors. 2.Catalog and technical data for the circuit breakers. 3.Catalog and technical data for the 15.0 Kv bus ducts. 00968 .wpf 9 ¢ 4.Catalog and technical data for relays,meters and instrument transformers. 5.Cross sections and details,as required,to satisfy the Engineers that all components conform with the specification and are completely satisfactory from the standpoint of design and physical arrangement. 6.Outline and assembly drawings complete with weights and dimensions. 7.Electrical elementary diagrams. 8.Layout drawings and bill of materials. 9,Support and anchorage details. 10.Installation,operating and maintenance manuals. ll.Documentation of adequacy of seismic design. 12.Spare parts list. 13.Storage requirements. 14.Design test reports. 15.Factory test reports. 16.Acceptance test reports. The Contractor shall submit such detail construction drawings,as are required, showing all details of the equipment and material furnished under this specification.Drawing shall be identified by serial number and descriptive titles showing their application to the systems specified herein. 00968 .wpf 10 COPY STONE &WEBSTER ENGINEERING CORPORATION TCritikos/Chron NABishop/JBK RPWynn JBYale .JGase CThomason Mr.D.R.Eberle January 9,1990 Project Manager Alaska Energy Authority J.0.No.19239.01 701 East Tudor Rd.WP 26A Anchorage,AK 99503 SWEC/AEA/2500 RAILBELT GENERATOR TEST ESTIMATE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY Attached is an estimate of the costs for performing tests of ten combustion turbines in the railbelt system. This estimate includes a pre-test trip by an engineer from PTI to visit the test sites,and coordinate the test schedule.Due to having three utilities involved at several sites,we believe that this coordination trip can save time during the test program.In addition,it will allow PTI to ensure that they bring all necessary equipment and personnel with them to the test. For PTI to perform the testing,prepare the computer models,and prepare and present a report,the estimated cost is $159,700 including expenses and contingency.For Stone and Webster to oversee this work,and review the test data,models and report,the estimated cost is $25,600.Thus,the total estimated cost for this work is $185,300. If you have any questions,or if we can provide further information please call. CLeadine.Gutilp Theodore Critikos Project Manager TC/JBY/CM NOT JA sO: cc:A.Kahn,AEA . N 1 0 90)crmoomn H.Clark,PTI Fea a amy JBL Oo Lone I. COST ESTIMATE RAILBELT GENERATION TEST PROGRAM PTI Costs A.Pretest trip to coordinate test and determine test required One week labor plus travel expenses $8,000 Mobilization and Demobilization Anchorage and Fairbanks .22,200 Test 10 Combustion Turbines/Governors Unit Cost $4,500 each Total Cost 45,000 Test 10 Exciters and Voltage Regulators Unit Cost $4,000 each Total Cost 40,000 Test 10 Generators and Develop Generator Reactances and Time Constants Unit Cost $2,000 each Total Cost 20,000 Report Preparation and Presentation, including expenses 10,000 Contingency (102)14,500 SUBTOTAL,PTI WORK $159,700 equipmen: II.SWEC COSTS A.Contract Change and Administration $1,200 B.Review of Pri Report 1,800 C.Administration and Management 300 D.Clerical 300 E.Participation in Testing 8,000 Expenses for Testing 4,500 F.Contingency (10%) |»300 G.Fee,2%of PTI 3,200 H..Expenses -Travel to Presentation Meeting,Reproduction,Telephone,etc.4,000 SUBTOTAL,SWEC WORK $25,600 TOTAL FOR SWEC AND PTI $185,300 tT.nw 4WWaxesoo'atior;iInc:ral Vi ta j ric Aesog ?Aye 2-7,RAL OFFICE:3977 LAK T REET @ PWROMER,ALASKA $0603 @ (867)236-8167 - IS kee " ALASKA ENERGY January 3,1990 AUTHORITY Mr.Dave Eberle ALASKA ENERGY AUTHORITY 701 East Tudor Road * P.O.Box i90869 Anchorage,AK 99519-0869 REFERENCE:P.T.I.Letter Dated December 13,1989 K.E.A.Letter Dated December 21,1989 Subject:Railbelt Load Shedding /Bradley Lake Studies,CT Testing Dear Dave: In response to the subject correspondence,we are also concerned with those issues stipulated and/or implied in P.T.I.'s letter dated December 13,1988. Aside from the Bradley Lake Surge Tank Analysis,it is our position that the Railbelt Load Shedding Study must rely onupdateddataandsyatemmodelingwhichwillreflectinformation current to that time we proceed with project startup. P.T.I.'s letter haa brought to our attention operational issuesthataremostdeservingoffurtherdiscussion.We encourage aformalproposalfromP.T.I.for turbineegovernor tests ag suggested in their above referenced letter. Perhaps it is time we,as Railbelt Utilities,meet to digcuss all curreot atudies,issues and projected modeling related to theBradleyLakePowerGenerationandtheTransmission.System)s).Inotherwords,we suggest a working group to start focusing on anintegrated"systems"operational plan that is based on currentinformation(studies)now or soon available to us.Prior to thefallof1991,when Bradley Lake is scheduled to come-on-line,HEAmusthaveareasonableconfidencelevelthatthisfacilitywillfunctionwithinsafestabilitylimits,operate reliably,andprovideeconomicoperation.. a rn SINS Ore ly ry[COARESPONDENCE DISTRIBUTION Bem Small Jneering Manager AEAPTI.TSS:kr ces;Kent Wisc Don Cornpl. Due Da te? CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska January 18,1990 TO:David Highers,General Manager VIA:Eugene Bjornstad,Executive Manager, Operating Divisions Michael E.Massin,Director,Engineering Division FROM:David-W.Burlingame,Manager,Facilities Engineering Jo SUBJECT:Bradley Lake TCS Meeting Minutes The following subjects were discussed during the Bradley Lake Technical Coordinating Subcommittee meeting held on January 17, 1990: Load Acceptance Analysis (Surge Tank Study)-Stone &Webster Engineering Company (SWEC)presented the revised addition of the study and submitted their recommendations.The study indicated Bradley Lake can provide 27 MW of spinning reserve without the use of the peak rating of the combustion turbines.If the utilities allow the combustion turbines to operate at their peak ratings for up to two minutes until Bradley Lake can reduce their load to something less than their base rating,Bradley Lake can supply an additional 67 MW of system spin.In summary,with the existing design and using the temporary peak ratings of the turbines,Bradley Lake can supply approximately 90 MW of spinning reserve subject to transmission constraints. An interesting item in the report is that for conditions where power is being imported into the Kenai,gas fired generation must be maintained on the Kenai in order to prevent a complete blackout if the single intertie is lost. Kenai Generator Test Report -SWEC submitted a report on the generator tests completed in September for all of the Kenai generation.SWEC also recommended the remaining units in the railbelt be tested.This recommendation is based on discrepancies between the model and field tests in each of the turbine governors tested.The committee requested a brief synopsis from SWEC detailing the major discrepancies. SCADA DECnet Interface -The utilities almost made a decision to finally drop the addition of DECnet to Bradley Lake with MEA and CEA voting to drop it,ML&P and HEA voting to drop it if GVEA couldn't sway them not to.However,GVEA wasn't present and ML&P/HEA changed their vote.Hopefully next meeting this issue will die. David Highers Bradley Lake TCS Mtg Minutes January 18,1990 Page 2 Bradley Governor -The governor was modified to include a third mode of operation which would improve Bradley's response to underfrequency conditions and load pickup.This mode will allow maximum use of Bradley for Spinning reserve and also allow Bradley to operate by itself with the Kenai islanded. CEA Microwave Installation -The committee recommended the addition of a microwave link between the State of Alaska and Chugach be included as part of the project costs. Project Schedule -A schedule was submitted which indicated the SVS and other stability aids may lag the project start-up by over a year. Project Test Period -AEA submitted a proposed schedule which allows for a "Project Operational Testing Period"to be included prior to the plant going commercial.This period would allow the utilities to operate and schedule power from the plant to ensure the plant is fully operational prior to being declared commercial.The period would be no less than 30 days and preferably not more than ninety.The committee approved the concept of the plan but did not address any specifics on its implementation. SWEC Reliability Letter -SWEC submitted a letter which addresses their concerns with the perceived reliability of the system following the addition of the proposed stability aids.The letter states they feel based on the studies performed by SWEC and their subcontractor PTI,the addition of a second line would be justified in greatly improving Kenai area and system reliability and would significantly reduce area outages and allow full use of Kenai generation.The letter is very positive in that it refutes previous AEA (Dick Emmerman)statements using the same studies. DWB/pv DWB3-38 ce:T.Lovas B.Evans R.Olson File 412 ( STONE &WEBSTER ENGINEERING CORPORATION GOOA STREET.SUITE 211.ANCHORAGE.ALASKA ADDRESS ALL CORRESPONDENCE TO 0.0.BOX 104479.ANCHORAGE.ALASKA 99510 TELEPHONE 907-276-1589 sosTon TELECOPY 807-277-7002 NEW YORK CHERRY MILL.N.J. OgnveR wousTon GALLAS PORTLAND.OREGON RICHLAND.wa WASHINGTON,O.C. Mr.D.R.Eberle January 17,1990 Project Manager Alaska Energy Authority J.O.No.15800.55 701 East Tudor Rd.WP 25A Anchorage,AK 99503 SWEC/AEA/2499 TRANSMISSION SYSTEM CAPABILITIES AND RELIABILITY BRAD DROE C_PROJE In association with the Bradley Lake Project,SWEC and PTI have recently completed several studies involving,inpart,the analysis of the existing Kenai to Anchorage transmission systems.These studies involved:(1)Kenai Export Limits,(2)Load Acceptance Analysis and,(3)the ongoing Bradley Lake/Kenai Transmission System Stability Analysis.Although none of these studies were directed specifically at the question of the feasibility of a new transmission line from Kenai to Anchorage,we believe that the results of these studies strongly suggest that a second transmission line from the Soldotna substation to the Universitysubstation,similar to the 138kv line being studied by theutilities,may be justified.The primary benefits of the new line would be improved reliability of service to the Kenai Peninsula and increased power export capabilities from Kenai to Anchorage. As a result of performing the Kenai Export Limits study and other studies we have determined that it is possible to improve the stability of the existing system using stability aids.However, this should not be construed to suggest that a more reliable system will be obtained once the stability aids are installed.The customary economic life for this type of transmission line is between 30 and 40 years.Even though some of the existing line conductors have been restrung,this is an "old"line.A 25 yearoldsingletransmissionlinewillstillbethesamelineafterthe stability aids are installed.The existing line will be stable, but it will still be the cause of relatively frequent customer outages.The number of customer outages can be expected to be over 12 annually. With the existing line and a new line in service,there will be a second line available to maintain the system interconnection if one line trips.Thus there will be a reduction in the frequency ofseparationsofelectricalservicebetweenKenaiandAnchorage.The 1889»STONE&WESTER +189ere.ner eeea new line will provide an improvement in the supply of reliablepowerfromKenaitotheAnchoragearea,and reduce significantlythefrequencyanddurationofKenaielectriccustomersoutages.It would take more study to determine the change in outage duration,but the number of customer outages could be reduced from over 12 to less than one annually.PTI has advised that "a newlinewouldfixthelongandunreliableSoldotnatoUniversity line."This existing line has historically experienced outages well above the traditionally accepted design criteria of one event per 100 miles per year. Current transmission planning practice is to determine the mosteffectivetransmissionupgrade,starting with the least costlyapproachthatmeetsstabilitycriteria,then building on it orconsideringothermorecostlyalternativesuntilabalanceis reached between cost (equipment,O&M,losses)and reliability.The recent SWEC/PTI studies have shown that with modern technology,low cost stability aids can provide stable operation right up to (or above)the transmission line thermal limits.Voltage problems,if any,are similarly solvable.Our studies performed to date do not quantitatively address the effect on reliability,the consequences of increasing power transfers,and the associated losses.Even though reliability issues were not studied,there are some obvious benefits to improve the reliability of the interconnection between Soldotna and Anchorage by the installation of a second transmission line between Kenai and Anchorage.It is our understanding thatDecisionFocusisstudyingthereliabilityaspect.We endorse that this study is prudent and necessary. If we can be of further assistance please advise. N.Bishop Deputy Project Manager NAB/JM 1 |me mid j i ia iHty rayingaiid |,ed:tif UintagutsithUNO FayeaeHyalaeNIUEHeatAHiiHHGyEeessenetennessssnnceadaensamensctiiINatyya { as ||(ja ae:al I.itt nnfea _- .|A aaiiiPeageVN iy Lakif ol 1iei if i Cie. .i nif i 41M;ee HO |a:(AN FEfaaaHone AR TECHNICAL COORDINATION COMMITTEE BRADLEY LAKE HYDROELECTRIC PROJECT MINUTES TUESDAY,NOVEMBER 10,1987 (At the Alaska Power Authority,Anchorage) Attendance: Dave Eberle Alaska Power Authority Oscar Johnson Alaska Power Authority Afzal Khan _Alaska Power Authority Vance Cordell Chugach Electric Association Bradley Evans Chugach Electric Association Dora Gropp Chugach Electric Association Paul Johnson Chugach Electric Association Tom Lovas Chugach Electric Association Del LaRue Dryden and LaRue John Huber,Jr.Golden Valley Electric Association Sam Matthews Homer Electric Association Tom Small Homer Electric Association Myles Yerkes Matenuska Electric Association John Cowley Municipal Light and Power Ron Krohn Stone &Webster Engineering John Yale Stone &Webster Engineering 3314R/CG I. II. ITl. INTRODUCTIONS The meeting was called to order by Dave Eberle at 9:00 am in theAlaskaPowerAuthorityConferenceroom.Each person attending introduced himself. PURPOSE OF TECHNICAL COORDINATING COMMITTEE (TCC) Dave Eberle informed the new members that the purpose of the TCC is to coordinate the technical aspects of the project with the power users in order to achieve an orderly integration of Bradley Lake into the Railbelt generation system.The meetings are semi-formal.The committee will discuss the issues and attempt to reach a concensus. APA will act as the final authority. The last meeting was held approximately one year ago.At that time the members were APA,CEA,HEA,and Stone &Webster as APA's consultant. OVERVIEW OF PROJECT Dave presented a slide show of the key features of the project. Handouts were distributed that addressed the generating capacity of the project.They are attached: Table 2 -Plant Generating Characteristics Letter of September 23,1985,SWEC to APA,entitled ENERGY GENERATION,BRADLEY LAKE AND SUSITNA HYDROELECTRIC PROJECTS A general discussion of the available generation followed.The amount of power available depends on the reservoir level (head).The tunnel and the units were sized so that with three units,each would be able to generate 45 MW at minimum head.For the two unit installation,the plant capacity at minimum head is 102.2 MW,and at maximum head is 117.7 MW (See Table 2). The curves and tables in the handout show the projected utility energy needs from Bradley Lake and the estimated available energy. Once the power Sales Agreements are final and more accurate energy use information is made available by the Utilities,APA will run the energy use analysis again.There is no specific deadline for this information.It is needed sometime during the next phase of construction. 3314R/CG Minutes of Technical Coordination Committee 3 Tuesday,November 10,1987 IV.CURRENT INVOLVEMENT OF TCC Each of the areas listed on the agenda were discussed. A. 3314R/CG Transmission Line Interfacing A one-line diagram (attached)was distributed.There will be two 115kv transmission lines from Bradley Lake joining a new HEA line from Fritz Creek to Soldotna,at a location designated as Bradley Junction.The lines will be "X"towers dead ended at the HEA line.Jumpers and motor operated switches will be used for the connection.Control of the switches will be from the powerhouse via VHF radio.Normal operation will be as two independent lines from Bradley Lake to Diamond Ridge and from Bradley Lake to Soldotna.Emergency operation as a three terminal line is also possible. The substation at the powerhouse will have a four-breaker ring bus using Compact Gas Insulated Substation (CGIS)equipment.It will be expanded to a five breaker ring if and when the third unit is added.The decision to use CGIS was based on economics due to the high cost of developing the area for an outdoor substation. System Load Flows/Transient Stability The studies performed to date by SWEC have been limited to performance of the generator on the system.EPRI load flow calculations were done assuming close in faults at Bradley Lake (most severe case).Clearing times of less than six cycles are required for stability.No examination was made past Diamond Ridge and Soldotna.Equally fast clearing times may also be needed further into the system. Three cases have been modeled for the governed stability of one unit operating isolated.They were for 20,70,and 90%of power and with load changes of plus and minus 5%.For each of the cases run,the units were stable within 120 seconds with a second speed transient in the same direction as the first of less than 25%of the first,and an initial speed transient of less than 5%.Additional cases can be run if the utilities provide the necessary load and load change information. The governors proposed to be provided by Fuji are solid state digital type based on Fuji's programmable controller.The control is contained in software.This gives greater flexibility to create a governing function that will keep the units stable when operating isolated. Minutes of Technical Coordination Committee & Tuesday,November 10,1987 3314R/CG Some concern was raised by TCC utility members regarding the reliability of the governor.A Governor and Stability Subcommittee was formed to address this concern and the stability requirements. Transmission Line Protective Relaying A permissive overreach transfer trip scheme will be used.This will give clearing in four cycles.As mentioned in B above, high speed relaying may be required elsewhere in the system. Revenue Metering Revenue metering will utilize Scientific Columbus JEM-2 meters, and revenue metering grade transformers with 0.3%accuracy.The measurement will be at the high side of the Bradley Lake substation with the transmission line losses to Bradley Junction calculated. SCADA Interfacing The SCADA system will need to interface with the dispatcher's SCADA system for dispatch of the project.APA stated it would be helpful to officially know who the dispatcher will be before the SCADA specification can be released for proposals.CEA and HEA confirmed that CEA will be the dispatcher and HEA will perform onsite operation and maintenance.Vance Cordell stated that CEA would sell an RTU to APA to locate at the project for the dispatch interface.This will eliminate any problems for APA if CEA changes protocoi. Communications -Dispatch/Protective Relaying Communications for dispatch via SCADA,and protective relaying will be by microwave.The state division of telecommunication's. (Div Com)existing microwave system will be used with the addition of terminal equipment at Soldotna,and a tower and terminal equipment at the Diamond Ridge substation.Currently HEA does not have the real estate at Diamond Ridge for a tower. Ron Krohn will contact Mike Ridge of Div Com to do a path study and advise HEA of real estate requirements.It was decided that the Communications Subcommittee would meet in a combined meeting with the SCADA Subcommittee at 2:00 pm on November 19,1987. Communications Maintenance Communications to remote portions of the site and along the transmission line corridor will be by VHF radio.A VHF repeater will be located at Eagle Lake by Div Com to provide transmission line coverage.Two channels will be provided.One is for SCADA control of Bradley Junction,the other for maintenance. Minutes of Technical Coordination Committee 3 Tuesday,November 10,1987 H.Breaker and Switch Identification Identification numbers are shown on the attached one-line.ThenumbersinboxeswereprovidedbyCEAtocorrespondwiththeir numbering system. V.TCC SUBCOMMITTEES Lists were routed for sign up for the technical subcommittees. Copies of the subcommittee member lists are attached.The technical subcommittees and next scheduled meeting are: Protective Relaying and Reliability -No meeting scheduled SCADA -November 10,1987 at 2:00 pm January 14,1988 at 1:30 pm Communications -January 14,1988 at 1:30 pm (same as SCADA meeting) Governor and Stability -January 13,1988 at 9:00 am VI.NEXT MEETING The next meeting of the TCC will be January 14,1988 at 9:00 am at the APA offices in Anchorage. VII.ADJOURNMENT The meeting was adjourned at approximately 12:00 noon. VIII.ATTACHMENTS Agenda Table 2 -Plant Generating Characteristics Letter of September 23,1985,SWEC to APA entitled:ENERGY GENERATION,BRADLEY LAKE AND SUSITNA HYDROELECTRIC PROJECTS Operational One-Line Diagram e Subcommittee Member Lists 3314R/CG AGENDA TECHNICAL COORDINATION COMMITTEE Bradley Lake Hydroelectric Project Alaska Power Authority November 10,1987 9:00 A.M. Place:Alaska Power Authority 701 East Tudor Road Anchorage,Alaska I.Introductions II.Purpose of Technical Coordinating Committee (TCC) III.Overview of Project A. B. C. D. Major Design Features Construction Packagina and ScheduleStatusofProjectConstruction(Slide Presentation) Project Operation/Monthly Generation Plan IV.Current Involvement of TCC crCOoOmMMIOw>yYTransmission Line Interfacing System Load Flows/Transient Stability T/L Protective Relaying Revenue Metering SCADA Interfacing Communications -Dispatch/Protective Relaying Communications -Maintenance Breaker and Switch Identification Vv.TCC Subcommittees A. B. .C. Protective Relaying SCADA (Meeting November 11,1987) Communications VI.Adjourn 720A/0027/1 TABLE 2 PLANT GENERATING CHARACTERISTICS BRADLEY LAKE HYDROELECTRIC PROJECT The plant capacity shown is on the high side of the main transformers and is based on an ultimate 3 unit plant output of 135 MW at minimum reservoir elevation 1080,an 11 ft finished diameter tunnel,and the combined main-transformer,turbine and generator efficiency. Maximum Maximum Reservoir Operating Tunnel Flow Output Level Units __(efs)(MW) Min.El.1080 1 unit 107 51.1 2 unit 1414 102.2 3 unit 2045 135.0 Max.El.1180 1 unit 740 58.9 2 unit 1479 V7.7 3 unit 2140 157.8 2-2212-JJ STONE &WEBSTER ENGINEERING CORPORATION A SIOL STREET.SUITE 310.ANCHORAGE,ALASKA ADORESS ALL CORRESPONDENCE TO PO BOX 104479.ANCHORAGE.ALASKA 99510 eostos TELE 007-277-2027 aw TONG TELCC OP 00%.3277.ORR Cogaav cm..us ocuver wemstFOnewWasennatou.OC Mr.D.R.Eberle September 23,1985 Project Manager Alaska Power Authority J.O.No.15500.72 334 West Fifth Avenue Anchorage,AK 99501 RECEIVED -SEP 2 4 1985ENERGYGENERATION BRADLEY LAKE AND SUSITNA HYDROELECTRIC PROJECTS CRA FAWER Preteen. BRADLEY LAKE HYDROELECTRIC PROJECT ALASKS FOWER AUIECAITY This is in response to your September 17,1985 request that we review the Harza-Ebasco September 13,1985,copy attached,and subsequently perform the additional energy computer run,as mentioned in the closing paragraph of the attached letter.You also requested an additional computer run using a variation of Matnuska Electric Association (MEA)energy requirements.We enclose copies of the four separate computer runs. Prior to undertaking these computer runs,I contacted Mr.W.Dyok of Harza-Ebasco and discussed the requirements of the attached letter.Mr. Dyok was in accord with the procedure for performing the computer runs. Since you may wish to review the enclosures prior to distribution,we are not copying Harza Ebasco or Mr.John Stafford of the Power Authority. In making our computer runs,we have attempted meeting the Utility Specified Operation for the Railbelt Utilities,as shown on Table 1 of the attached letter,while maximizing the firm energy generation of the BradleyLakeProject.Our approach for maximizing firm energy,while meeting targeted monthly utility needs,was to operate the plant at the averagecapacityvalueneededtogeneratetheenergyrequiredforthatmonth.The computer run results show the Bradley Lake Hydroelectric Project come close in meeting the Utility Specified Operation for the Railbelt Utilities as shown on Table 1 of the attached letter. The computer results are shown on Tables A,B,A-l.and B-l,attached. Data on Tables A and B are for a 90 MW installation;and Tables A-1l and B-1l are for a 135 MW installation.Further,Tables A and A-l relate to targeted Utility Specified Operation values as given on Table 1 of the attached letter.The computer results given by Tables B,and B-l relate to the targeted Ucility Specified Operation values;however,the MEA monthlyenergyvalueshavebeenadjustedinproportiontothesumoftheCEA,AML&P and HEA values.This approach was discussed with you and Mr.W.Dyok. -2=- If you are in agreement with the computer run results you can pass these on to Mr.Stafford for his September 24,1985 meeting.Please contact Ted Critikos (303)741-7126 at our Denver Operations Center if there are any questions,as I will be away from the Anchorage office. 7"Caigche J.J.Garrity Project Manager JIG/TC/VT Enclosure TABLE A MONTHLY ENERGY GENERATION TARGETED UTILITY SPECIFIED OPERATIONS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY TARGETED UTILITY 90 MW BRADLEY LAKE ENERGY GENERATION MONTH OPERATION MIN()MAX(*)AVG JAN 42,400 37,140 37,140 37,140 FEB 41,100 36,001 36,001 36,001 MAR 34,100 29,870 29,870 29,870 APR 31,400 27,504 27,504 27,504 MAY 24,700 21,636 21,636 21,636 JUN 20,100 17,606 17,606 17,606 JUL 20,100 17,606 78,964 21,950 AUG 19,300 16,905 76,335 29,579 SEP 20,400 17,869 76,335 39,481 oct 32,800 28,731 76,335 33,652 NOV 40,300 35,300 36,488 35,348 DEC 42,400 37,140 37,140 37,140 TOTAL 369,100 323,308 482,702 366,907 (7)Minimum energy values represent firm energy. (2)Energy generated at wettest month of record. 1814£/0089£/VT TABLE B MONTHLY ENERGY GENERATION PROPORTIONED TARGETED UTILITY SPECIFIED OPERATIONS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY TARGETED UTILITY 90 MW BRADLEY LAKE ENERGY GENERATION MONTH OPERATION MIN(*)MAX (¢)AVG JAN 47,055 40,645 40,645 40,645 FEB 45,259 39,093 39,093 39,093 MAR 36,294 31,350 31,350 31,350 APR 30,158 26,050 26,050 26,050 MAY 22,816 19,708 -19,708 19,708 JUN 15,086 13,031 13,031 13,031 JUL 18,086 13,031 76,022 17,322 AUG 18,086 .13,031 76,335 26,570 SEP 16,624 14,359 76,335 38,S95 oct 33,319 28,780 76,335 33,897 NOV 45,259 _39,093 39,094 39,093 DEC 47,055 40,645 40,645 40,645 TOTAL 369,097 318,816 490,761 365,999 (7)Minimum energy values represent firm energy. (2)Energy generated at wettest month of record. 1814£/0089f£/VT TABLE A-1 MONTHLY ENERGY GENERATION TARGETED UTILITY SPECIFIED OPERATIONS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY TARGETED UTILITY 135 MW BRADLEY LAKE ENERGY GENERATIONMONTHOPERATIONMIN(!)MAX(*)AVG JAN 42,400 37,140 37,140 37,140 FEB 41,100 36,001 36,001 36,001 MAR 34,100 29,870 29,870 29,870 APR 31,400 27,504 27,504 27,504 MAY 24,700 21,636 21,636 21,636 JUN 20,100 17,606 17,606 17,606 JUL 20,100 17,606 98,855 22,866 AUG 19,300 16,905 108,042 33,434 SEP 20,400 17,869 92,695 41,170 ocT 32,800 28,731 77,333 33,692 NOV 40,300 35,300 36,488 35,348 DEC 42,400 37,140 37,140 37,140 TOTAL 369,100 323,308 482,702 373,407 (7)Minimum energy values represent firm energy. (2)Energy generated at wettest month of record. 1814£/0089f/VT TABLE B-1 MONTHLY ENERGY GENERATION PROPORTIONED TARGETED UTILITY SPECIFIED OPERATIONS BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY TARGETED UTILITY 135 MW BRADLEY LAKE ENERGY GENERATION MONTH OPERATION MIN(T)MAX()AVG JAN 47,055 40,645 40,645 40,645 FEB 45,259 39,093 39,093 39,093 MAR 36,294 31,350 31,3580 31,350 APR 30,158 26,050 26,050 26,050 MAY 22,816 19,708 19,708 19,708 JUN 18,086 13,031 13,031 13,031 JUL 15,086 13,031 103 ,832 18,435 AUG 15,086 13,031 108 ,043 30,449 SEP _16,624 14,359 92,874 40,372 ocT 33,319 28,780 77,333 33,937 NOV 45,259 39,093 39,094 39,093 DEC 47,055 40,645 40,645 40,645 TOTAL 369,097 318,816 490,761 372,808 (4)Minimum energy values represent firm energy. (#)Energy generated at wettest month of record. 1814£/0089£/VT "ewer'HARZA=EBASCO SUSITNA JOINT VENTURJITHSTREETANCHO TEL.(907)272 8885 sep 17 1985 SWEC-ANCHORASE RECEIVES September 13,1985 . 1.8.2/40.11.4.2 SEF 1u 1985 ALASKAPOWERAUIHORIEY Me.James B.Dischinger Project Manager CONMIDSNTIAL:PR'VILEGED WORKAlaskaPowerAuthorityPRODIPINT2ALANTICIPATION334WestSthAvenueOFLITTRESTRICTEDAnchorage,Alaska 99501 DISTR UTION Subject:Sueitne Hydroelectric Project Bradley Lake Energy Generation Dear Mr.Dischinger: Per your request we have reviewed the information you provided us on Bradley Lake project operation in your July 28,1985 letter.In addition,we have reviewed the document ve received from Stone end . Webster Engineering Corporation on July 2,1985 pertaining to «May 9, 1985 meeting on Bradley Lake Project Energy Generation. In Table 1 attsched,we show the monthly energy requireseats for esch utility based on their eetimated annual allocation,sesuming an everage auuual wusrcyy of 369 GWE.Since che rower auchoricy nas coc receivea « response from MEA,we assumed monthly energy generation equal to 1/12 oftheirannualallocation.The resultent monthly energy generations insumermonthsisapproximatelyhalftheenergygenerationinwiatermoaths.This is s compromise of the Power Authority's proposed operationofmaximizingfirmenergywithequalmonthlyenergygenerationand Chugach Electric's proposed operation of minimal summer generation asillustratedinTable2.In Table 2,non-firm operation (columns |and 2) represents the wonthly energies resulting frow che energy distribution assumed by Chugach Electric.Project operation is etructured to meet the Chugech Electric target energy every month irrespective of firm energy. The constent generation case (columns 3 and 4)represents the Power Auchority monthly energies resulting from the distribution contained in the Bradley Lake FERC License Applicatioa.The minimum or fira monthly energy for non firm operation (coluan 2)is substantially lees chan chat of constant generepion (coluam 4)and in some aonths during dry years caabeclosetozero d/ta reality,the stored euamer energy would be released in « somewhat differeat senner during winters in which chere te {fneufficient reservoir storege to meet the target requirements. Sualtna File Capy 401091/9 Fie @ Mr.James B.Dischinger September 13,1985 Page 2 The aoa-fire operstion annual energy of 375 GWH in Table 2 is 55 GWHgteaterthanche320GWHreferredtoinanApril12,1985 letter from BobHeathtoMr.Robert Martin of Chugach Electric.It is our understanding from Stone and Webster that the information concained in the April 12, 1985 letcer was based oo «prelimiaary run made in early April.This preliginary run is superseded by the deta in Table 2.Given that the non-firm operetion minimum energy drops to near zero in late wiater and thee this would likely be unacceptable to ucilities,Stone and Webster wade an additional computer run specifying target energies between the noo-firm operation and constant generation cases.However,the results were not included in the package we received from Stone and Webster on July 2,1985.MNonetheless,Stone and Webster did include information in the July 2,package which according to Stone and Webster approximstes the additional computer run. Sheete 1 through 4 dated May 9,1985 present Lotus 1-2-3 calculations of minimum,maximum and average monthly energy for different operating goale.Sheets 2,3,and 4 show en average annual energy of ebout 365 CWH acd @ firm annual energy of 310 to 318 CWH for a 90 MW installation. Since each of thase operating goals yield average eannuel energies close to that of constant generation (sheet 1)and have less summer energy generation than utllity epecified operation,we think thet che utility specified operation provided in Table 1 may meet the needs of Railbelt utilicies with Lietle reduction in firm or average energy.We therefore recommend that the utility epecified operation be incorporated in Susitua related work.However,an additional computer run should be made to verify thet there is little or no reduction in average or firm energy. Project Direetor ce:&.Carter,HE W.Dyok,HE J.Stafford,Power Authority D.Ryan,Stone &Webscer G.Vollaad,HE 401091/9 TABLE 1 BRADLEY LAKE HYDROELECTRIC PROJECTMONTHLYENERGYBASEDONUTILITYSPECIFIEDopeRaTron(!) 401091/9 UTILITY CEA AMLAP 8 AEA MEA SES FMUS GVEA TOTAL Alloeation(2) Percent 30.0 28.2 11.4 12.7 1.1 4.2 12.4 100.0 Peak (MW)27.0 25.4 10.3 11.5 1.0 3.7 1l.1 90.0 Energy (GWH)110.7 104.1 42.1 46.9 4.1 15.5 45.7 369.0 Monthly Energy (GWH) JAN 15.9(3)10.8 (4)6.05(5)3.9106).36(7)1,550823.8109)42.4 FEB 15.0 10.8 5.70 3.91 34 1.55 3.81 41.1 MAR 12.0 8.7 4.56 3.91 034 -78 3.81 34.1 APR 10.5 6.5 3.99 3.91 -34 2.33 3.82 31.4 MAY 6.0 7.6 2.28 3.91 "234 78 =.81 24.7 JUN 261 7.6 0.80 3.91 3%1.55 3.81 20.1 JUL 2.1 7.6 0.80 3.91 -4&1.55 3.81 20.1 AUG 2.1 7.6 0.80 3.91 034 -78 =8=3.81 19.3 SEP 3.6 6.6 1.37 3.91 034 -78 3.81 20.4 Oct 10.5 8.7 3.99 3.91 «3%1.55 3.81 32.8 NOV 15.0 10.8 5.70 3.91 034 78 8=63-81 40.3 DEC 15.9 10.8 6.05 3.91 -34 1.55 3.81 42.4 110.7 104.1 42.2 46.9 4.1 15.5 45.7 369 (1)Assumes total annual energy of 369 GWH.If annual energy ie different values in Table 1 should be proportioned. (2)Based on forecast of 1988 energy requirements. (3)Monthly dietribution besed on March 25,1985 letter from R.Martian to R.Heath and corrected April 18,1985. (4)Monthly distribution besed on Auguste 12,1985 letter from T.Stahr to J.Diechinger and adjusted to 104.1 GWH total. (5)Same distribution assumed as CEA based on telephone log of J.Stafford dated July 12,1985. (6)Xo reeponse received.Equal monthly energy generation aseuned. (7)Reference April 25,1985 lecter from P.Diener to J.Diachinger. (8)Reference July 18,1985 letter from V.Gillespie to J.Dischinger. (9)Reference July 11,1985S letter from M.Kelly to J.Dischinger. TABLE 2 BRADLEY LAKE HYDROELECTRIC PROJECTENERGYGENERATION(!) (2 X 45 MW INSTALLATION) Non-Firw Operation(2)(3)Constance Generation'2)UtilityRequirenents (4) Average Mininue Average Minious Monthly Monthly Monthly Meathly (Fire)(Fira) JAN $3 $3 28 28 42 FEB 48 12 28 28 41 MAR 35 1 28 28 34 APR 25 0 28 28 31 MAY 18 6 28 28 25 JUN 7 ?28 28 20 JUL ?7 7 32 28 20 AUG 16 7 38 28 19 SEP 25 12 43 28 20 OCT 38 35 33 28 33 NOV 50 $0 28 28 40 ° DEC 53 _33 28 _28 42Annual]375 2695)369 334 369 (2)Prom Stone and Webster (3)Meets CEA target energies each soath irrespective of firm energy (4)Froa Table 1 (3)poes noe equal sum of monthly minimum energies because monthlyminimumesergiesaretakenfromdifferentyears,vheress 269 CwH represents the minimum annual energy from the historical record, corresponding to 1974 401091/9 -OF-MAY-8S we SHEET 1 OF 4 (CHUGACH ELECTRIC LOAD SIMULATION STUDY BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY $MIN MAX (#)AVE MIN MAX (@#)AVEMONTH(MWH)3 CONSTANT !90 MW INSTALLATION i 133 MW INSTALLATION GEN.|ORIGINAL ENERSY TARGETS {ORIGINAL ENERGY TARGETS POLICY !(MWe)|(PWH) t { | t t { i + 3 !FEB 27,838 |27,638 .27,842 27,840.!27,827 27,827 27,827 MAR 27,638 |27,838 27,842 27,840 |27,827 27,827 27,827»@PR 27,838 |27,38 27,842 27,840 |27,827 27,827 27,82?»Y 27,838 |27,838 27,842 27,840 |-27,827 27,827 27,827 | -UN 27,838 |27,838 27,842 27,840 |27,827 27,827 27,827 |JUL 27,838 |27,8358 66,112 31,838 |27,827 66,169 31,867 |AUG 27,838 |27,838 74,3535 38,540 |27,827 102,267 41,480 !Ser 27,8638 |27,858 76,335 435,185 |27,827 92,542 44,541 |!OcT 27,838 |27,838 76,3535 32,810 |27,827 77,300 32,838 | NOV 27,658 |27,638 36,488 28,186 !27,827 34,485 28,173 '1 {(aw)t (eo)t. NNUAL 334,062 !334,062 475,828 349,261 {333,919 801,702 373,686 | OTES: (©)'MAXIMUM MONTHLY GENERATION DURING THE PERIOD OF RECORDS (#@)GENERATION DURING THE WETTEST YEAR C9-MAY-85 an SHEET 2 OF 4 CHUGACH ELECTRIC LOAD SIMULATION STUDY BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY |OESTRED |!90 MW INSTALLATION §i3S MW INSTALLATION t CHUGACH !ATTEMPT TO MEET {ATTEMPT TO MEET ' ELECTRIC !LSAD (MWH)LOAD (Met)s :LOAD H MIN MAX (#)AVE t MIN MAX (#)AVE tMONTH(MWH?=f t t JAN SS,000 |43,982 43,982 435,982 !43,982 435,982 43,9782 1FEB50,000 {41,493.41,495 41,493 !41,4935 41,495 41,493 3!40,000 |335,394 35,2194 35,294 §33,294 35,194 =S55,194 135,000 |29,043 29,045 29,045 !29,045 29,043 29,045 3 20,000 !16,597 16,597 16,597 |.26,597 16,597 16,597 1!UN 7,000 |!7,000 7,900 7,000 |7,000 7,000 7,000 |!FUL 7,900 !7,000 73,949 12,362 I 7,000 97,5352 12,226 !AUG 7,000 |7,000 74,335 235,190 !7,000 108,042 26,784 |SEP 12,000 |9,958 74,535 39,825 |7,758 96,976 41,728 !ocT '35,000 |29,045 76,335 34,432 |29,045 77,3335 34,492 |NOV 30,000 $41,495 41,4935 41,495 ,41,495 41,495 41,493 !i §(a)3 (ae)1WAL349,000 I 309,790 497,859 345,616 t 309,790 S31,790 372,237 | ES: (#)MAXIMUM MONTHLY GENERATION DURING THE PERICD OF RECORDS (#@)GENERATION DURING THE WETTEST YEAR O oe Ty. ui O9=MAY-85 a SHEET 3 OF 4 +CHUGACH ELECTRIC LOAD SIMULATION STUDY | BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA POWER AUTHORITY DESIRED |90 MW INSTALLATION {335 Mw INSTALLATION -CHUGACH |HIGHER SUMMER GENERATION 1 HIGHER SUMNER GENERATION .,ELECTRIC |(Mud)t CPt) ;LOAD $«6©MIN «=6MAX (#))0 AVE Of MIINOMAX CH)AVE MONTH (MWH)|t JAN 53,000 |43,724 43,724 43,724 1 43,724 43,724 43,724FEB$0,000 |41,250 41,250 41,250 |41,250 41,250 41,25 .MAR 40,000 |32,999 32,999 32,999 |32,999 S2,999 32,999|PR 35,000 |28,874 28,874 28,874 1 28,874 28,874 28,874 wAY 20,000.!16,8500 16,500 16,800 !.16,300-14,800 16,800 JUN 8,000 |8,000 8,000 @,000 +98,000 8,000 8,000JUL8,000 |8,000 75,954 12,2871 @,000 97,992 13,169AUG8,000 |8,000 76,335 23,688 !8,000 108,042 27,442 SEP 12,000 |9,900 76,335 39,202 1 9,900 94,901 41,057-OCT 35,000 |28,874 76,335 34,265 |28,874 77,3335 34,304NOV30,000 |42,249 41,249 41,249 1 41,249 41,249 41,249DEC$3,000 |43,724 43,724 43,724 1 43,724 43,726 43,724 |(a)4 (aw) NNUAL 372,000 {311,097 497,400 S&S,731 {311,097 531,146 372,294 ITES3 (#)MAXIMUM MONTHLY GENERATION DURING THE PERIOD OF RECORDS (##)GENERATION DURING THE WETTEST YEAR OF-MAY-BS we ae SHEET 4 OF 4 CHUGACH ELECTRIC LOAD SIMULATION STUDY BRADLEY LAKE HYDROELECTRIC PROJECT |. ALASKA POWER AUTHORITY ad t | DESIRED |-90 Mid INSTALLATION {i335 Mw INSTALLATION ! 'CHUGACH {!HIGHER AUG SEPT GENERATION!HIGHER AUG<SEPT GENERATION! ELECTRIC |!me)f (MH)i LOAD {MIN MAX €#)AVE [MIN MAX (@)AVE MONTH (MMH)a t ,t ES: )i (@)MAXIMUM MONTHLY GENERATION DURING THE PERIOD OF RECORDS (#0)GENERATION DURING THE WETTEST YEAR 7)"Tr .TvVi-as-008S!|4 't rs ,. 7 qf +alpenDelERTig©2%Cs) 3€38 we fosn (2325) ovvue-eeu?God NSAV BUS OFUS 18 mA =eoapStSS = am [eon Fore fon [ver jane lee:re |ee [ret [ecel ace fants ate|ee een aes -F we]concen |om [00 |ee :-./|4 FL m -soues-xor 3}ue ->te a .NEVI 2F PAR 4)a %4 .:|Lt °.=a ry ;=PROJECT REVIEW #-Y 15,1986 SUBMITTAL 7" .ae rs -13 -- -5 _2 Po.2 NAL ONE-LINE DIAGRAM :{4 -t -HYDROELECTRIC POWER PROJECT . ASH A POWER AUTHORITY e + --}==-' beter Engineering Corporation B.wonjoen}--4 ¢ee ve i wealooe or) ==Gd anciao=A Ga ==="15800-FE-1A :weetd -oe PROTECTIVE RELAYING AND RELIABILITY SUBCOMMITTEE NAME Oscar Johnson Afzal Khan David Burlingame Bradley Evans Paul Johnson Steve Haagenson Sam Matthews Tom Small Larry Hembre Ron Krohn John Yale NAME FIRM Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Municipal Light and Power Stone &Webster Engineering Stone &Webster Engineering SCADA SUBCOMMITTEE Oscar Johnson Afzal Khan Vance Cordell Paul Johnson Fred Lebeau Sam Matthews Tom Small Bob Day John Yale 3316R/CG FIRM Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Municipal Light and Power Stone &Webster Engineering NAME COMMUNICATIONS SUBCOMMITTEE Oscar Johnson Afzal Khan Vance Cordell Paul Johnson John Huber Sam Matthews Tom Small Ron Krohn John Yale NAME FIRM Alaska Power Authority Alaska Power Authority Chugach Electric Association Chugach Electric Association Golden Valley Electric Association Homer Electric Association Homer Electric Association Stone &Webster Engineering Stone &Webster Engineering GOVERNOR AND STABILITY FIRM Afzal Khan David Burlingame Bradley Evans Dan Rogers Sam Matthews Tom Small Myles Yerkes Ron Krohn John Yale 3316R/CG Alaska Power Authority Chugach Electric Association Chugach Electric Association Chugach Electric Association Homer Electric Association Homer Electric Association Matenuska Electric Association Stone &Webster Engineering Stone &Webster Engineering Bradley Lake Technical Coordinating SubcommitteeMeetingMinutes July 19,1990 Morning Session The previous meeting's minutes were approved. The majority of the morning session revolved around the scopa ofservicesforStone&Webster and AEA's position on whether or not the system studies were part of the project.It was eventuallyagreedthatthesystemstudiesrequiredtoincorporateBradleyLakeintotheRailbeltwerepartoftheproject. Stability Studies For the purposes of the interim stability study,it was agreed thattrippingofBradleyLakeunitsduringsystemdisturbanceswasacceptablesolongasitdidnotcausealossofloadandimprovedsystemconditions.Unit tripping should be used as only the lastresorttoavoidthecomplicatedtriggeringschemeoriginallyproposed.The tripping of generation units during systemdisturbanceswillnotbeallowedatothersites,but will be allowed at Bradley Lake to increase the capacity output of theplant.SWEC indicated this may alleviate the need for the brakingresistorsatBradleyLakeandwillsubmitsupportingstudycasespriortothenextmeeting. The Committee reviewed the stability cases required for interimoperationone-by-one and adopted the cases with minormodifications.Reclosing will be enabled on the 115 kV lines,but can be modified to prevent reclosing into a faulted line from theBradleyLakeside. Single-Pole tripping and reclosing will be employed on theUniversity-Daves Creek Line. After the Daves Creek -Seward line is reconstructed to 115 kv,itmaybepossibletoselectivelyrecloseforonlynon-symmetricalfaults,however until the line is rebuilt,reclosing will beemployedonallfaulttypes. Generator Test Reports The Kenai generator test reports will be available by August 1,1990.The remaining test reports for Beluga and ML&P will beavailablebyAugust15,1990. SCADA A list of Chugach SCADA points at Bradley Lake was distributed and approved. HEA Line Status HEA stated the line from Bradley Junction to Soldotna will be completed by April 1,1990. SWEC made a formal recommendation to not pursue the use of seriescapacitorsonthe115kVsystem.The recommendation was adoptedunanimously. SWEC stated they would not endorse the triggering scheme proposedbyPTIforusewiththebrakingresistor.They also stated the useofunittrippingwillprobablyeliminatetheneedforthe triggering scheme. SWEC indicated they would be reluctant in recommending the use ofthebrakingresistor.The committee agreed the resistor's useshouldbestudiedifitallowsagreatercapacityoutputfortheplant. Chugach and HEA agreed to review the overfrequency constraints todeterminewhatthemaximumoverfrequencyallowedontheKenaiwouldbeacceptable.Chugach has since determined that an overfrequencyof63Bzisacceptablefromitsgenerationstandpoint,so long asHEAindicatesitisacceptablefortheirgenerationandconsumers. The committee has agreed to accept a Fuji analog stabilizer on theBradleyunitssolongasacceptingthecheaperanalogstabilizerdidnotputanycapacityconstraintsontheplant. The committee recommended proceeding with the procurement processforthebrakingresistorconcurrentwithSWEC's review of its use and application. The utilities requested an expanded detail of the start up andtestingfortheBradleyLakeunitsaswellaswhatgenerationrequirementstherewillbefromChugach/AEG&T to support the tests. David Burlingame was elected secretary and Vice-Chair replacingMylesYerkeswhosoldouttoprivateenterprise. File 410 BOSTON CHATTANOOGA CHERRY MILL NS cHicaco DALLAS DENVER OT.LAUDERDALE MOUSTON STONE &WEBSTER ENGINEERING CORPORATION yN 5500 SOUTH QUEBEC STREET ENGLEWOOD,COLORADO 80111-1914 ADDRESS ALL CORRESPONDENCE TO P.0.BOX 5406,DENVER,COLORADO 80217-5406 W.U.TWX:910 935-0105 TELEPHONE:303 741-7700 FAX:303-741-7670 W.U.TELEX:45-4401 RCA TELEX:289251 303-741-7671 NEW YORK PORTLAND.ME PORTLAND,OR RICHLAND WA RICHMOND.VA SAN FRANCISCO TAMPA WASHINGTON.OC. July 13,1990 Mr.David Burlingame J.O.No.19239.26 Chugach Electric Association WP26A 5601 Minnesota Drrve SWEC/AEA/2600 Anchorage,AK 99519-6300 The next meeting of the Technical Coordination Subcommittee (TCS)will be held at Alaska Energy Authority beginning at 9:00 a.m.on Thursday,July 19,1990. On behalf of the Energy Authority,enclosed is the agenda for the meeting and the following attachments for your review: 1. 2. 3. 4. 5. 6. 7. Minutes of April 24,1990 TCS Meeting SWEC letter dated July 9,1990 --Interim Operating Limits Study FUJI Power System Stabilizer Data SWEC letter dated July 12,1990 -System Stability Solutions Bradley Lake Project Test and Start-up Program Final SCADA Dispatch Points List Minutes of May 22,1990 SCADA Subcommittee Meeting Stone &Webster will also be distributing a revised Stability Study and Procurement Schedule during the meeting. Please notify the appropriate individuals within your organization of the upcoming meeting and distribute the advanced materials accordingly. US eodefe Crifikos dy Project Manager TC:LW Attachments ccs Mr.David Highers Cugach Electric Association 1999 *STONE &WEBSTER ©1/989 Iit. IV. AGENDA BRADLEY LAKE HYDROELECTRIC PROJECT TECHNICAL COORDINATION SUBCOMMITTEE MEETING Held at the Offices of Alaska Energy Authority 701 East Tudor Road Anchorage,Alaska July 19,1990 9:00 AM APPROVAL OF APRIL 24,1990 MEETING MINUTES APPROVAL/MODIFICATION OF AGENDA OLD BUSINESS A.Kenai Generator Test Report -Status B.Stability Study and Procurement Schedule C.Final SCADA dispatch Points List D.CEA/DIVCOM Microwave Link -Status Report (CEA) E.Harmonic Amalysis Data Status Report (CEA) F.Interim Operating Limits Study NEW BUSINESS A.SCADA Subcommittee Report B.FUJI Power System Stabilizers Cc.System Stability Solutions,SWEC/AEA Letter of July 9,1990 D.Brake Resistor and Deflector Run Back Triggering Study E.Testing and Start-up Plan (RECORD COPY.ms FLENO . 720 AY |D EGEIVE ses 4/ay jaaMayi41990BRADLEYLAKEPROJECT ALASKA ENERGY TECHNICAL COORDINATION.SUBCOMMITTEE Minutes of April 24,1990 Meeting The meeting came to order at 9 AM at the offices of Chugach Electric Association inAnchorageAlaska,In attendance were: ATTENDANCE:AFFILIATION Myles Yerkes -MLSP Jehn Yale SWEC Dave Eberle AEA Gene Biornstad CEA David Burlingame CEA Steven Haagenson GVEA Ray Olson CEA John §.Cooley ML&P Don Shira AEA Afzal Khan .AEA 3JimHallMEA/Jack Anderson SES ; Maynard Gross HEA Sam Matthews HEA/AEGT Minutes of the previous January 17,1990 meeting were approved as drafted.TheproposedagendafromABAwasapproved. Dave Eberle briefly discussed the final Load Acceptance Analysis report issued April,1990, AEA advised that the final report on the Kenai generator tests should be completewithrequestedTCSchangeswithinthenext60days.Work has been delayed toexpeditethePIImachinetestingprogram. AEA advised the committee that the DECNET software has been purchased fran the SCADA contractor at a cost of $116,700.Delivery will be in 1991 prior to projecttestingandstartup. John Yale presented a revised schedule of activities required to define and installsystemstabilityequipment.After significant discussion,SWEC agreed to revisethePIIscheduleofstabilityStudiesto: 1.Comply with previous TCS requirements documented by mem of October20,1989 fram Myles Yerkes to David Eberle. 2.Establish clear TCS review and approval points with adequate reviewtime. Page 2 3.Provide for TCS involvement and approvals in all procurement decisions including:- a)Specifications b)Final solicitation documents/bid documents c)Prequalifications a)Bid evaluations e)Design verification studies John Yale discussed the status of the brake resistor and stabilizer procurement. Basically,the schedule provides for formal,advertised bid procurement resultinginfinalinstallationbyNovember,1991.This may create project start up delays since AEA now anticipates machine on line testing in spring 1991.AEA advised thattheywillattempttonegotiateanearlierdeliverythroughFUGI.The committee supports the negotiation approach to secure early delivery.AEA will also amendtheprocurementdocumentstoincludethebrakeandonlythatportionofthe13.8kVbusworksbetweentheresistorandthebreaker.The 13.8kV bus tap and breaker will be provided by a change order to the Powerhouse Contract.This will allow machine testing to occur without interuption during installation cf the resistors. of the resistors., lave Eberle distributed a memo fran CEA dated April 9,1990 which discussed yrohlems and conflicts in purchasing the equipment fer the new CEA headquartersmicrowaveGownlink.Conflicting purchase regulations may result in incompatibleequipmentbeingpurchasedifAEAandCEAindividualypurchasetheirownequipment.CEA proposes to purchase all equipment with complete reimbursement fram AFA.The AEA half would be turned over to Diveom for installation and maintenance by then. The committee recommends acceptance of the CEA proposal by AEA and the ProjectManagementCammitte. Under new business,John Yale discussed the status of system stability studies nowunderwaybyPII.All studies except subsynchronous resonance (SSR/SSO),andmachinetestingareessentiallyonholdawaitingtheoutcomeofthesetwostudytasks.PII is experiencing significant difficulty in obtaining shaft informationforexistingGeneralElectricgasturbinesthatiscritical.to the SSR/SSO studies. CEA indicated an apparent error in the value of the CEA/MLEP (230/1L5kV) transformer at Plant #1 yard.PTI should check this immediately. SWEC distributed a handout from PTI titled "Task 3 =System Stability Studies andEquipmentSpecifications",All utilities were asked to review this document and provide requested information and comments directly to Dave Eberle and John YalepriertotheendofMay. The next discussion concerned an unsolicited proposal fram PTI to conduct harmonic sampling and analysis on the Kenai peninsula at a cost of $50,000.The camittee jreed on the need and benefits,however,much of the sampling has already beenwonebyCEAandthedataisavailableforanalysisintheirAnchorageoffices.ThecammitteerecarmmendedreducingthescopeofworktoanalysisoftheexistingCEAdata.Other proposed studies of electric and audible noise were rejected. Page 3 John Yale distributed a "Draft Specification for Static Var System in the KenaiPeninsula",consisting of 84 pages,and dated March 1990.Again,utilities wereaskedtoprovidecommentsdirectlytoDaveEberleandJohnYalebytheendofMay. The next business was review of an RFP from AEA and related proposal from PIT to conduct studies of interum operations,prior to addition of stability equipment,as required to establish Bradley operational limits during this peried.In general,the utilities were concerned with the limited study scope,and possible damage to the system fran limited studies.AEA agreed to expand the studies so as to provideconclusivesafeinterumoperatinglimits.Dave Burlingame and Mike Yerkes will prepare a revised scope of work for AEA/PTI review and cament within the next two weeks, The camittee now reviewed minutes of the March 1,1990 SCADA subcommittee meeting. AEA pointed out that under Part II (A)of the minutes,the IOC must address interfacing the project with the existing railbelt software. AEA raised the question of project revenue metering.Currently,metering isprovidedonthe115kVbusoftheBradleypowerhouse,however,the power sales contract specificies all power is delivered at Bradley Junction.The camittee recommended installing electronic compensated kilowatt hour/demand meters at the project site which will directly indicate power and energy delivered by each lineatBradleyJunction.The schedule/dispatch committee will addreas how systemlossesintheHEAsystemaretobecalculatedandallocated, SWEC will camplete protective relay settings for all project facilities and providethecommitteewithrecommendedsettingsandbackupcalculations.Dave BurlingameremindedAFAthatallsettingsmustincorporatethefinalsystemstudiesandconfigurationnewbeingcompletedbyPTI. Next AEA gave a brief update of the railbelt generator tests,now underway inAnchorage.Mike Yerkes summarized problems testing ML&P Unit #4 which is equippedwithaWoodwardgovenortype301control.PTI had no previous experience withmonitoringthisunitandconsiderabledifficultieswereencounteredwhentrying tocomnecttestequipmenttothecamputerinputcards.In response,CEA indicatedthatPTImistsummarizeallanticipatedconnectionstotheCEAWoodwardcontrols,and Woodward would be required to review and approve such connections prior toscheculedtesting.ABA indicated that this activity would delay scheduled testing.AEA and CEA agreed to meet the following day to resolve concerns. The meeting adjourned at approximately 1 PM. sunireainteHMM IPEMyles'C.Yerkes,Nice Chair Approved: Dave Eberle,Chair REAR VIEW |!=a ps (meee eMUTE -FESER TU DeG,19919250 £64YokDEbanFOuMe Wika BaP l th. Ch "Aypa aru*- we nde ar - 4|Tt Be> ith eje ac | Ep ie li |_||]4 EY a3 #1 esuuefiee wel |stayFdaostopechFaelt..ren fH I i |Ha eeeley| ||==f |=ge ||'Hy ;i.|L__ba Wa Wa Gale||--ste :Vyas HW IE:veelWili2edheSy| ._Foon |:[Cn oro =I mea |2} UH i cantina]Aigos'ets}seuh ase i, fancied a ou'p &v8)"gee)ass |if FIHAL DRAWINGA AUX.RYN :ASSEMBLY DRAWING OFie..A $ayy'as ea beat B -_-a "a <Ly =AYR CUBICLE =StS a bee|obeestes]PSrhem 2 }se poe a es ed eed st CONTRACT NO.2890033 "os wo |oe |Lee |oe we |oe ve |a BRADLEY LAKE HYORGELECTRIC POWER PROJEC =fee o-sa |oe we |oe ALASKA POWER AUTHORITY WPce da,ree ZS MEF oN om 1)i]a0 1 eo ae PD ¢end ves ry)ES ee tEwerk:::aid arene cit -_tar PARED)"OG Fy ko]Gece,sth ches ed aesiae ft ' .YTS351362% SECTION A-A DIODE STACK 2xA.CT LQONT VIEW INNER FRONT VIEW tw.cnA {[s]iT YV C ".!"pO:°Yor pone:ve l r 1 u {H soe soa :,1'9 e$0K © we ot auto0OToyVOLTAGE1 aan "7 SCITER FOLLOW-UP i 10 .,i 7 .->{CONTROL 1 ov -}-|Babance-[-]|][i ||{|3 (7)|METER Bw a _-H-:°PROPORT |ONAL-INTEGRAL BATE PULSE !ee|_T LS La WD [Active |dq GROSS CONTROLLER |connotea ' hon ae .:POWER .1 an t )7 tuunien LIMITER eis ("T |i [-ay>--3 .=i on . : ; ee,AL ' 3 =NX .af \°1 23 l--+4-] . ! ae LIMITER !pt we POWER | 7°"[SYSTEM ' STAB IZA).' SUA ete 1 Auto |._|_ :th _->t-«=SYHCHROWIZING SIGHAL*(FOR AUTO).a += "wan -t = -+-jet.=(7-1)SVHCHAONITING SIGNAL (FOR MANUAL) ox oo. "oe -)Gdeer"SEME{--t-}>cl|--_++-J " 32|--+-]0 Ae 22(-}L=An. PROPORTIONAL-INTEGRAL .GATE PULSECOKIROLLERCONTROLLER 900x?FIELD CU2eeMt porn =SETIER SUPPLY ----15wife EON ©sot som ,A tPOWERTT . :fe]p)'e?-7-2 OAte |Nave ful AUTOMATIC VOLTAGE ='Bit coon at saito||Fant Eyctde Cond [2]REGULATOR 3 W4108008 Ju am,POWER SYSTEM STABILIZER (PSS) 1.General description of scwer system stabilizer -oe" 2.Synehronizing torque and damping torqve in each exciting .systen .3.Swnehronizing torcue and demping torque in scwer system stabilizer io: 1 it(iG {Date}Name,boy yb pdr |Bo-5 Ahi ad i°' :4 i| ss 'i jr heracion |Cheeted $_=nit tet Ae ee AoneaePUNE OEsmeeee He ee eee He OM Mime mecermrm seesamee oe Ul ionatn - ed -”n WwAaiS)oN "dl dadcelNNH 3 " v a3 F 0 ie a fen ksi) ry) C)pe wv el ;r m rt a " 1) aj ? ha w W(3 3 v , & Q a§ ry Ou G : Oo u a * Ht}GC u: Le) vvCi) cs Sieber -_-- Gi] eT 0] or o ort aG v ov Me G w ort oOsoog4%w Ct] = @ q ol w ue] eq Oo t 'A el a Coan VU od ¢- d u u| oe M4OoaCT)Gcc)©] l. 2. l. \ 4 rovsi rytrdet-e oa Ef tw - anne aries pomnomsweteaeames - eigen oor comesanmeat comes Lew -- ae ee 2a ane we ee "ryrs =] ' we lL.Oscillation equation Eq.(1)shows the kinematic ecuation octained when 2 Generator supplies power to a system in a singles machine .infinite system model. it a"6 +2 a6 HS Tm -TA cee ccc cece cee cece eee c ees Ch) 9 t wo ct where,M:Inertia coefficient- C Tm:Mechanical input torque .6:Rotor phase angle D:Demping coefficient -Te:Electrical cutput torque .Wo:ni rad/sec In the normal state,Tm and Te are baiancec and stationary at a certain internal phase angle (6). However,the power system is slightly disturbed by lead variations,etc.at all times.But even in such cases, . the generator can be operated stably cwing to the suppression °torque expressed with the rotor pnase angle Aé in phase and the suppression torque expressed with rotor speed du in phase. The former is a torque component to attempt returning the 7 |synchronous machine action to the original baelenced soint |and called synchronizing torque,while the latter is a =torgue to camp the cscillation of the synchrcenous machine 'nnod a DotDi ij it j Date 1 Name ||i20ee|Fuds ELECTRIC|; i item!-=|}| |eet. H 'iAinersion |Coeesed ! and called damping torque.The oscillation produced by disturbance is suppressed by both components descrinec above.However,if either synchrcenizing torque or camping torque or both torques are deficient,the stabilizaticn of the synchronous machine cannot be maintained any longer, causing the machine to be stenped out. 2.Retion of generator at small pertubation onid{:...-.oe.Es.(1)is linear apsroximation for smail variaticns. In this case,Te is aifected by the field circuit in practice.However,"Te is proportional to Ai,if che Fisic linkage flux remains constant. Assume K;:(synchronization coefficient)be its cceiticient, .and we obtain;ATe =K,;48 J Thus,Eq (1)is modified to Eq.(2). i a?-,D 4 woKkyr ,-say «(AG +t =AG +--46 =0 .........2...weeee(2ateMdtM } "i Since the above equation is a secondary differential ecqua- tion,it becomes an oscillation type when the camping coefficient is 9p <l with reference to the step insut. t i ts anguiar frequency (uw)is given by Eq.3. .ce|-os {- oo.wo =wny l=pt aa GE :; _wnere,on =Kiwe/M (Inherent angular.trequency) :og ;:D -____wes: i ps 5 /\XiMwo (Damping coelticient) /| ;od' i i i ! t ; ;i Liars |Name |j 1 a ---a 7.-_'jf Litera!-!|Fadi SLEOTRIC |4 fo.i Trace #Sed -||H '+| é5tarmmewereseendcomeaFrom Eq.(3),the oscillation cvcle becomes sooner as K, becomes larger or M becomes smaller.Since the camping is :=3 os -puwntdeterminedbyacoefficientof2puns ,it becomes sooner as D becomes larger. From Eq.(2),the differential term finally zero ané Wak -::.S221 ag =ATm holds true,if the other constants remain constant,regarding small pertubation A4Tm.Thus as K, becomes larcar,15 becomes smaller,2nd resultantly,cne oscillation becomes smaller. This oscillation cycle changes accoré¢ing =o M,D ane KX,as Gescribed above.It is said to be about 0.5 2Hz in actual operating condition or about 0.1 3Hz in ssecial cases.Whether or not the oscillation is attenuated is important from the standpoint of stability. Fig.1 indicates the oscillation modes by sign of D. A6 Adi a6)|| a Nee|t |c |iS a)D=0 Continuous D>)D>O Attenuated ec)D<O Divergent oscillation oscillation oscillation Fig.1 Oscillation modes according to damping coeificient eeeeeearrgi Drown ! _-.#tberecec, (Attest awe tell cca ?(2{(8_J 2.Synehronizing torque and damping torque in each exciting system 2.Synehronizing torque and damping torque when the field linkage flux remains constant (,2.Synenrenizing torgve anc damping torque when the .firld voltace remains constant 3.Svynehrenizing torcue and damping torcue with AVR provided i ! t o q Dag .3 oo,é oe :;re |so 5 ft q - °3 3 ei aa l t 8 3 nseeaad}Date |Neme |i Di |jal --|1 Faxed?SLEDVTRST | i 1 ; i.|'I teeese |--_||7 i reeset "aot 4 =t '!i |Coie :: i Alteration |Ciscses |-_-!}' ( 1.Svnehronizing torque and damping torque when the tielc linkage flux remains constant Specified generator output value !. GOV -O=-*(Standard frequency value)-T AE Ta |A (Frequency) 4 (Mechanical input wo torque)37 4 :;OQ 2S :vo -"$-ss Xe) dTe Au)A (Phase LO angle a)A (Elecerical],(p,5i5 D wo gle) torque)-torcue)A (angular LAr velocity)+ATC%s ¥xavesTY.S (Syneazo=1"Tez [+"sizing | H |torque)i t :iKy K. °j ? | :Aga!|K |-* .:ecg |6 .Y :: i +BEt K 'A (Terminal i 1+STdo'K4 ||voltage) - t e x,"o Ets--'+i (Standardivoltage SEfd AVR |value) 4 (Field ° voltage) Fig.2 Generator block when field linkage flux remains constant (For calculation method of this block, refer to Win 52335) i Assume 4Te +ATL =ATe ;D D F -Aw 'ATe.=K,46 +D-3 ........4 :D 1 we teeter sees (2) i 1 , 'i Date H Name {3 .71 rr 4 s>«=e :7 a FuGi ELECTRIC | ' : .'. nee |Treeee | tAlterstion |Cheeses |eeeterend Since ATs and 46 as well as STD and 4w are in-phase components respectively and also duwshows 90°leading phase as compared with Aéd.the synchronizing torque and damoin torcue when the field linkace flux remains constant is expressed by vector a diagram as shown in Fig.3. Aw uy) ATn +---_ATeDC/j B} f ! t t ! i A6 ATs AS Au) -WO Fig.3 Synchronizing torque and damping torcue when field linkage flux remains constant Fig.4 indicates K,K,,6 and Ve when the effective power was increased with a power factor of l,and also Fig.5Ax shows K,Ke,6 and Vo when the reactive power was changed with the effective power set to 0.5 (1/2 load),as i examples. { T ; é : } os :OS o egy' i * L 1 t e ' i:ae To BG |Date 1 Name ||! 3 -Hameed BA oT.Sern 3t|icume |_--||>PP esease Lien,2 BSS | or N 'Poy og r r .to,i Traces |--||-!ame o--7 ; ::i ' ? ::A See oy ee Ste ia 'Alteratioe Leicee |-_!!|| £)VG KL . K2 KS Fig.46 Ki % K6,6 and VG when K3 1 "QG =0.0 field linkage flux K4 |Xd =0.92 remains constant x6 Xd'=0.30 1.5L 0.16 Xq =0.66 Xl =0.14 i Tdo'=3.8 sec H 1.4 0.14 1.2 0.12 K2 \ | '2.0-0.20 - VG 3 {rad/sec]} 0.8-0.08 Ch 6 0.6F 0.06 K3 0.4-0.04 J / a O.2F 0.02 K6 0.2 0.4 0.6 0.8 1.0 PG - 0.2 -0.02 KS -0.4 -0.04 on Po =0.5 Xd =0.92 Fig.5 KL K6,6 and Xd'=0.30 Vg when field Xq =0.66 linkage flux Xl =0.14 vesains constant Tdo'=3.8 see 2.56r ; 2.0F XL L.st R2 83 KS K6 Ve6 1.0L l 0.5. | { . H -0.5+-0.054 t 1 1 "1.0%$-9.104 10 2. remains constant Synchronizing torque and damping torque when field voltage Specified generator outpuc value ! cov _Fs (Standard frequency value) tat : 4Tn .lA (Frequency)A (Mechanical input wotorque)on >1 |.-O _m3 Bo >o AG ATe 4 (PhaseSTpfyangle)A (Zlectrical (D wo .'tore:Damping angul\torque)torque)aeuter Amiahs XL ser 4 (Syachre-! nizingrorque)--)___ K2 KS | Eq!6 oy i ;Sec :K3 i:4 (Terminal ;"-'voltage) i 1+STdo'K3 t =-A+ '+K4 U Ets ..}i (Scandard ,i AEfd :volta eA(Field |value|voltage)AVR { !:!Fig.6 Generator block when field voltage remains i constant Assume ATe +aT,=ste, i KiX2X .:dTe,=K,A6 ---222 46 i D '+.r)1+STd,'K3 46 -:=(k,+Kids +(D+Dt)Le.(3) ; -oo ; ;;|Date |name |' io? _op)fae =S||Fad?SLECTHIC |12 tos oe !|-_-fom eed way __-a me :'1 ' .T -.1 GUS \: S - tAlleratios |Crecsew f _-_-|!||=aoewes where K,'= i) K2K3Ku D'=woK2K;*KuTdg'L+(wTdo'K;)*'1+(wTd)'K;)*eos envre eae (6) Synchronizing torque In Eq.(6)Kz and K,are positive when 65 <180°and K;is always positive.Accordingly,K,'becomes necative. - The synchronizing torgue is K;when the field flux remains constant,while the synchronizing torcue when the fielé voltage remains constant becomes smaller wnan K,,because of the Gemagnetization action caused dy tne In the normal state;(w =0); Ki'(w=0)=-KoKyKu cece ccc ee eee eee eee eee cece (7) The stability limit is given by; Ki KiK3;K,=O Lec ccc cw cee ce eee wwe ere eee ee renee eee ee (8) Similarly,wnen w >> '1 _K2KuK,(w >-TaT Ky Tutdag'')*K3;ee ce eee eee ee ee (9) ané the stability limit is given by; K2Ku _Ky Tota,)eK,=O°:ws eee eee we eee eee eee H t ve --T . : ;{beatae ]Name}}\,.;="my CS -swd con tenontor ' i |Drnenf ||Fett ELECTRICS !12 Isrscea!'faced:-=H i ''' i.SB LymActaracinnbel_-i ||83.Ea | vem00eensyO' 1)Damping torque From Eq (6),D'has the positive sign.Accordingly, the damping torque is D when the field flux remains constant,while the damping torque when the field voltage remains constant increases as D+D'. l .:When w >-RaTTEG ,we obtain; ty KoK .D'(yy >>mr)eS wee c cee wee cee ee (113259Agwide Outsut 'Pir.7 shows che Slock diagram when the fFisid voltace remains constant. Ay 1 wo wo 46 MS |s | || D+p'4 ' i F A 1LStsvSts|xi +KL Fid.7 Block diacram when field voltece remains constant a:'t|Name |:|13 .4 |7 --1 ''1 ||cGLTE "reomensmeeeSmetaemaneceeeentesmeeeestes©coutteeeememeressnesThis can be expressed by vector diagrams as follows. ky wo ATep'od ATy' ' A6 'Ag ATS!mS "j.42wo Fia.8 Constant ciale voltage Fig.10 and 11 indcicate damping torcue when the as examples. the synchronizing torcue and bw Wo OTept+4Tep ' ATep ”_Fic.9 Overall éiacran field voltage remains.constant,iebootPoet:!yas ; . to i]aie |Name {'14oy-t $¢=":=Sellamteead'en aeUraws;_-||;3 esate ER=o F Ya | toa ' FL '1 'i _.traced!__{|a t 4----:'me . -i |CHLTSiAlteration|ereceee |-_--|\OTH 1.6 Fig.10 Synchronizing torque and damping torque when field voltage remains constant "0oO Fig.Ll Synchronizing turque anu damping torquewhenfieldvolcageremainsconstant 3-0 Pg =0.5 Xd =0.92 D!Xd'=0.30 Xq =0.66 Xl =0.14 2.5 Tdo'=3.8 sec -ws 10 wo =2m x 60 -2.0 1.5 1.0 0.5 -1.0 -0.4 0.2 0.4 0.6 0.38 1.0 -0.5 -1.0 1.5 3..Synchronizing torque and damping torque with AVR proviced Specified generator output value + GOV mOre:Fs (Standard frecuency value) ne,.i A (Frequency)-jA (Mechanical input : torque)wo 27 é 2 So -7 MS s AR bTe |aw Aw A (Phase &(Eleetrical]"*D D 30 angle) torque)A (Damping QO (Angular torque)velocity) [ATs a-4 ($ynenro-CTeF =nizingrorque)1 K2 S|'Te ;AE t 71+ !=£q K6 St i See :ece i 3 &(Tersinal :1+STdo'K3 voltzge) = K4 Az_: +C =tSs (Scanderd AEfd volrage A (Field value) 1 voltage)AVR :Fig.12 Generator block ci2gram with AVR proviced H : i Date 1 Name |! --Fuk aTRic |+7 ononary 2aan" Assume ATe +4T,=ste,and Gaye is)be the AVR function. _dw |__K3K2{Ku +KsGayr(S)}:ATe,=Kidé +Do -TyStagyKy +K3kKeG.._(5)°°AVR =(Ky,+K,")a6 +(D +p")Se ceecceceeeeeceees (12) let's KE be AVR function,as we obtain; ) K,"-K2K3 (Ku +KsKe)(1 +K3Ke Ke)(1 +X3XeK_)?+(uTde'K3)? °Se (13) pe =W2K2K:*Tde'(Ky+XsXe){l +K3KeX)7 >(eTd,'K:)? let's K,1+STs 1 be AVR <unction,and we obtsin;=ST,i+ST, ,; ) :K,"= K2Ka{Foi-Fo3 +w°"Fr2°Fou}{F.,}?+w*{F..}? 1 t eee erewe eereee (14) i p"woKeK;{(F22°F23 -F2y-F2s} (F2i}?+w?{F22}? :J K3;KeK ]-A3HKGKE _2 ase -7where,F2;=Th w*(Tdo'K3 T.,)| l t i Fo2 =1+K3Ke kK.-w*Tde'KiT, poo ete eres ec oes (15) P23 KsKe w?KV,lTy | Foy =Ka +K5K_ ;/ i bate |Name j fires}-=|Fu)SSTTRes|18 1 \Feacea!__|- ;-|OF 27 rs |i 1A iteration |Coscaed |-_-|a .NET ©) Fig.13°Ks characteristic according to operation conditions Xd =0,92 E€£ective Xd''=0.30 oa power |Xo =0,66 °Xl =0,14 -0.06 a -0.04 Tdo'=3,8 sec -0.035 -0.03 -0.025 -0.02 -0.015 -0.01 -0.005 |\| T.0 0.5 0.0 0.5 Reactive povec __Reactive power(leading)enna (delayed) 1. t a i ! 4 ' | ' ed ' : | | 1 4OunceeeeeIn Eq.(13),(14),and (15),Kz and K.are positive when 6 <180°and also K;and Ks are always positive. However,Ks becomes either positive or negative,cepending upon the operating conditions.Ks is positive with a light load,but it becomes negative with a large line impecnace and a heavy load,in general.However,Ks also becomes negative,Gepending upon the power factor. Fig.13 indicates the Ks characteristic when generator ? ané Q change. Drews | |Traced i >ifLAlteration|Covcted }-j1___li-4' |Fins:ELECTS |20 tl ?iAlteratien©Crectes 1; (1)Synehronizing torque In the normal state (w =0),Eq.(16)is obtained from Eq.(9)and (10). RyKe ke Ks,Kr K2K TA "TAK,"(w =0)=243 (Xake Ke)TA K:Ksee ceewwerecececewees (16Ks } Ki is negative with a Light load (Ks;>QO)and it recuces the synchronizetion.It is also sostivie with 2 heavy load and increases the synchronization. When AVR is Ki,we obtain Eq.(17)fzem Eq.(13) H K»K;(KsKe +K.)i Ky"=e-Ses -cece cece weer eee ee (17:Ky 1 +Keke ee eeee (17) °:.:.-K;This equation is the same as Eq.(16),if K,>>==and,5 l;Ky eee Ol -(17).;&K3K¢n Eq () i vi)Damping torque Since Ks is negative with a heavy load in Ea.(64), D"becomes negative to decrease the camping tercue. This pnenomenon becomes larger as Ko becomes larger,and when it becomes noticeable, 'D+oD"<0, i Thus,the negative camping causes the svstenm t |Date |Neme |1 5Onesl==||Fs ELSCTRIC|21 }. _-Tree!=-|--7 |CG.LTS a Q ' | { .' an)i .odt ' PAlteretion \ rd t ' ' oscillation to increase with time.Thus,the step-out mav result. If Ks is samll and TA is larqe,the system oscillation is reduced.However,the generator voltace rise ratio (AV)increases when the load is turneé off (including remote end load shut-ct Fig.15 indicates the block diagram with AVR provicec. &u) ata i 130 0 AS xS 5)} TytiTp"|| d=5D"ae 4 ' ' " i ATS+ATS Kl +x1" Fig.14 Block diagram with AVR This can be expressed by vector diagrams as <ollows. } !' i ow dTeD bo A Aw |\'|:|"e : | ' q \ ATs"a) -Ao A6 -A6 '7 STeDTAT ED" H 'Hi'7 :|/"!0 t QTp ||/:!\i dw !v|eT ete"-fo |Tey" 130 "*eD ed Pig.15 Vector diagram Fig.16 Overall vectorwithAVRprovideddiagram ;Date |Name } brews]--|;Feud ELECTRIC :22 Teacee _-|'\ fASQ 2 ws Z : !1 tCaweted K1+KL"(w #0) q1.51 e-* an K1+K1"(w =10) 1.0F AVR 140.25 1QG=0.0 61:° ta =0.92 0.25 1+0.025 Xd'=0.30 Xq =0.66 Xl =0.140.5 Tdo'=3.8 -w =10 wo =2m x 60 K1"(a=) 1.0 Pg KL"(w =10) -0.5-. -1.0- "1.5. -2.0. -2.5. Fig.17 Synemronizing corque and Camping torque with AVR provided-3.0° 23 Figs.17 and 18 show the synchronizing torque and damping torque with AVR provided,Fig.19 indicates the damping torque when generator P anc Q change,and also Fig.20 indicates the synchronizing torque and damping torque when the AVR gain and integral time constant i Alterssion |Cosevee | chance. L \ \i :i 4 ee Std tt 2 { co oe 8 : pod !° :!Hi '5 ApitjDare|Name|l i ¢'-ty [bee ==T |Fu?SLECTRIC |24 ee ee _-:{'ies ::'m _|3 , i |CG.L72 roi! t .1 Wh 3.5 4 i Po =0.5 |Xd =0.92 t Xd'=0.30 I Xq =0.66 \X12 2 0.14 I Tdo'=3.8 3.0 5 p"WY =10 \wo =27 x 60 \ [AVR -_-"61 1+0.25 1 2.5 i 0.25 140.025 I. l ce ; oo j { 2.0 &\ i t . j 5 11.5 }I ,) ,Fig.18 Synchronizing torque and j damping torque with AVR 1.0 |Gj 1 provided .| °'s 0.557 KL +KL"(w =10 q -G -1.0 -0.6 Femme KL"KL"(wo =Q) (w=10) "0.5L D "1.04 25 Xd =0.92 Fig.19 Xd =0.30 AVI ;Xq =0.66 1 +0.25 1DampingtorquewithAVRprovidedXL=0.14 61 0.28 10.026 tdo =3.8 sec Effective w=10 power wo=2x x °? -1.0 aa -3.0 et -2 0 -1.0 1.0 0.0 ' 5.0 7 . 7 - -!n 0.5 0 0.5 1.0 Reactive power (leading)- ----------=-Ieactive power (delayed) Kl innv°ue™q0.5 K1+K1"(TAsO.1) Pg =1.0 Qe =0.0xa=#0.92 Xd'=0.30 Xq =0.66 Xl =0.14 Tdo',=3.8 w=10 wo =27 x 60D"(TA=0.1) D"(TA#2.0) =D"(Ta=00) é K1+Ki"(TA=0.4)oer"(qae?.0ye RL+X1"(Ta=00) D"(TA=0.4)=1=0.02S 5 10 15 20 'AVR gain (KE) Fig.20 Synchronizing torque and damping torque when AVR and integral time constant change where,KI+Kl1"when weO is 1.781, irrespective of KE and TA. 7 D"(Ta=0.1) 5"(taso 4)Nw ! 3.Synchronizing torque and damping torcue in power system stabilizer 1.Introduction TZ.Synchronizing torcue and damping torque when AVR .-er :(sh):is provided with angular velocity (oe )@etecticon0 type PSS combined 3.Synchronizing torque and damping terque when AVR is provided with rotor phase angle (Aé)éeteciica type >SS combined. 4.Synchronizing torque and cemping torque when aVR is provided with power (A4Te)detecticn type PSS combined. i 5 :oPGi |1 J Geaee |Traens.--i 28 tAlterenen |Peeenee! AYIntroduction In section 3,'we describe that the damping torque recuces when AVR is provided with a heavy load,causing the machine to be stepped out. This section deseribes the power system stabilizer (PSS) which gives an auxiliary signal to AVR so as to increase the damping. The PSS sicnal should fully take the delay of the synchronous machine and AVR exciting system into cue consideration,and also compensate che delay over tne entire frequency ranse. However,it cannot be realized easilv from the viewocints cf hardware,and also a frecuencv component having én angular velocity of 5 20 rad/sec comes into ovestion in tne oscillation frecuencies which avvear in the vower system usually. Accordingly.the above frecuency comconent must be taken into due account,and also the eiiect by an increase cr a Gecrease of the load (angular velocity change)during manual operation of the guide vane must be surpressed. Accordingly,we obtain the following equation as a ?SS function,while taking the above factors into cue consideration. Dogi |Traces! fas H :lAterstion }ChoeeeeI KP +t re x a -t x G 2)veeeeee (18) j j |Date !Name !' |Oreen i -|||Pui SLEDTRIC |29 ;j ;i -1 |; er ,CE.LTES !I ' 94 1+sTProvidedthattheparenthesizedl2St may be omitted,.Vv depending upon cases. The angular velocity (ara ),rotor phase angle (dé)oz effective power (4Te)may be used as a detection signal of FSS. This section intrcéuces the generator block Giacrams when AVR is provided with a2 or Aé @etection type PSS combined, and mainly described tne 4Te d@etection =yse 2SS which is generally employed now. ifs.! 3 : 1 |Drown: en an 1 Traces, :VAlverazion |Coecsee!IN é 2.Synchronizing torcue and damping torque when AVR is &.provided with angular velocity (oe )detection type PSS combined. Specified generator output value !+ GOV ( Fs (Standard frequency value: ATn -Tos -15 F-|Q (Mechanical input ="(Frequency)torque)on |+1 ° |g s 2TN 6 te oy A (Phase"ATp ;ao.angie)A (Electrical nue torque)4 (bene ess 4 (Angularvelocity)A+ATs KioTeF14(Synchro-nizingcorque) K2 PSS ,KS AEq'K6 24 = A=t -__A (Terninal 1+STdo'K3 voltage) -_l4 K4 CS Ets *+|(ScandardA(Fi rin |voltage ie volzage)AVR value) Fig.21 Generator block diagram when AVR is provided ae du sg :.::witn ave eetection type PSS combined. Q :|Date |Name || | (oj feel |Foc!ELECTRIC |3 2 it Traced |__-i :en }To !:: |Alteration |Coectez |_-|!=y = Nt Let's ATe +aT,= Sass Now,we optain; 4Te,,G (s)be AVR <. AVR function and also (s)be PSS function. iS} ;-K2K3(KutKsG (s)--G Vv (s)G,(s)}Ate ,=K,45 +Doe +AVE We AVR 288 Aé °L +S Tdo'Ks +K3KsG,.,.(s) -K2Ki-Gy,(S)Goce (S)=(K,+K,")4é+(D+p")44 =Wo AVR 2SS A8 *Wo Ll +STG 9'K;=Ki KsGyy2 (5S) =re'"n x we =..tte Aw 193)3=(K,+Xk,+X,)A6 +(D +3 DT)-ee ee (13).wo bdo dos 4 ;abPidfads body 2 bob et PE |Date |Name |||,bot t inert ==|||Fut SLECTRIC |32 en ee .soo |Trecee |_-_-||CGLTE {i '\' i Alteraticn |Coeete |_-||| 'Dy Alteration |Taeceee |-_- 3.Synchronizing torque and damping torque when AVR is provided with rotor phase angle (48)detection type PSS combined.; Specified generator outpuc value J . +Fs (Standard frequency value)Gov Y ; -_--Af Ata |A (Frequency) 4 (Mechanical input no torque)27 C-i 0 .--MS E}Fate) dTe at Avy A (Phase&(Electrical |"79 wo angie) torque)A (Damping 9 torque)4 (Angular I+ATs velocity) C palAter&(Synchro-°i nizingtorque) R K5 1 -vr +f=q K6 > a K3 SEt h+STdo'X3 A (Terainal {voltage) = =K4 PSS bene Ets AEEd "|(Scandard A (Field voltage T voltage)AVR value) 13 : bo:i en .-ri Fig.22 Generator block when AVR is provided with 2 8 yt id 66 detection type PSS combined ploDtt {Gate |Name 3 :¢red _-r1|\Drews|==$ouiGi ELECTRIC |33 i!!'|Traeed |_-_-{i . 3 |||ll .Let's ATe +AT,= Gogg (S)be PSS ATen: function. G (s)be AVR function,andAVR Ne a Now,we obtain; "-K,K3{K.e +K5G -G,G } Ate,=K,A6 +Doe +AVR___AVR PSS"46 o Ll +STd,'K;+K3KsGaun (8) K2K36,.,,6 _-wy Hayat =n dw .AVR Pss=(Ky +Ky")46 +(D+DYDD *TO SFa Ky =RsksGaynlS) =(XK;+K,"+R,")26 +(De dD"ed™)SLL...(20)wo j Date |Name \ t {ae Cf.i72 ae 'Specified generator output value Synchronizing torque and damping torque when AVR is provided with power (ATe)detection type PSS combined Gov )-Fs (Standard frequency value) Sf ATa la (Frequency) -_-one :woA(Mechanical input =torque) +L wo_XS Ss ; ATe Ss > A (Electrical |ATp es &(o3355torque)D Ao 4 (Danping .torcue)4 (angular +ATs velociry) ''Klater<(Svachro-porcus)} K2 K3 | +4 + AEg'K6 ' ac K3 A (Terzinal L+STdo'K3 voltage) -y+ ©K4 -Ecs +(Standard voltage defd value) A (Field AVR voltage) PSs Fig.23 Generator block when AVR is srevidéed with cower (ATe)detection type PSS combined !!1 Date |Name |veret =m |Fu3i SELSCTRIC 35 Traeeni _-_||° ;,weer a. |__-4 'CO.LF z. - "4.( '=<3 LLet's ATe +'T,ATe,,Gayp ls)be AVR function,and also Gogg (8)be PSS function. Now,we obtain; Aw K,(1 +STd ,'Ka)-K2K3Ky+KiGaye (Ss)(Kike-K2Ks5}4Te,=D-+AS Wo L +STdo'Ky +K3G.y0(S){Ks +X,G36 (8)} =k"a6 +(D+pm)42 be ceeeeecceececeeees (22) Wo .1 +ST,1Assumei.we A AVR Function and ->st i+STL. .aA 3 7 j T ?x *t a "Tx se PSS function"ep Testy Dest,Dstt,"Pe cere Then,Eq (22)is ootained., Fai *F322 +w*Fa2 -Fay K,™= {Fai}?+w?{F32}?; ,wee wee ee eww wee wees (22) FaicF3u -Fs2°Fa33 Dp"=Wo {F3 dt Rs){P32}? } where, K3KsK. ;2=-'k +T -TT «+¢Cf -TT 'Pay T,w*(Td ,'K3 +T3)}{1 w (TITY tty Try)3 |-2 +%,=:2mA 1%,m m =™-3°?nTSw°(1 X3Ke Ke w°Tdo X37 2)(T,Ty ty Pe Tuly) :a4 a tSa 2KOK;KX TT,(&2aPitoRRKERoTTyCay7Ty) Dh | pric ae Peta |a ,i {|Date |Name ||=1 1 4 diveent -=|\|Fuki ELECTRIC 36 :Treceo|--_{:ry t '''|-_-,j SaLre -SA lpeestunaler..-|--|i}H H = KaX6K,2 }2 --'k -Fi2 =i w°(Tde 'Ks;+T,)(Ty +TM +Ty ”TET yTy) +(L +K3KsX.-w'*Tdo 'K3T)(1 -w2(TLT,+TT 7T,T,)}cI B L M LX MX 2 Ty -7 7 -(7)KKK KITT,(L+7) (Kak,7]F33 =a a (Ki Ke -K2kKs)-wo?(T,(K,-K2K3K.)=Tea Ri Kay |LUA . py) x {1 =y?2 +7 TT +T-(2 =wo (TTY +TTY +TyTy) w?{KaX_(Kixs -K2Xs)=Ki} -X2X38.-weg 'KiX3T5) .7 =wpx(TL +Tu +rx w Tr Tuty) [se 7}Fas =](K,Ks -K2ks)-w?{T (Ki "KiK3;K.)+Téo'KiK33 3 \°2 x ,1 -2(Tr +Ty +Ty -wT TTY) +{Kak (Kike -KoKs)+Kk,-KzK3Ku -w?Td 'X,X3T,) x =.)2%(7 i D{1 -o (TTY +TT,+TyTy)} wee eee ee eee (23) PYG i |a Assume Ku.ST L +St pe AVR function ancre-A "Bésdt? bai: :|i ST,1+sTPaKyramen--ote PSS function a P od.ST,1 +Sty 3 8 |1 .i]. soho toa fpettedpdbPTitELD Date Name||,ido ie =]||Fasdi SLESTRIC |37 ' | '|;7 H!!|' p -faced |_-_||o | t1AleeratsanHotote]! Then,Eg.(24)is obtained. K we F3i°F33 +wF32°Fae 1 2 2 ,}2(Far)ui tP a2) 'seceeee See eeeees (24) DY =u,a =fiz 7Eis{F31}*+w {F32} wnere- K3KeK .Poy =(gE -w*(Tde'Ks +TQ)}(1-0?TTY)C A ;-wo?(1 +K3Ks®3 -w°Tdg'K;T2)(Ty =Ty) n.oN-w?K2K 3K,KT,(L +7, .K3K,K.;Fy2 ={3%-wi(Td,'K3 =T,)}(T,+Ty)A +(1 +KikeK,-w?Tdo'KaT,)(l -w?T Ty) »KeXjKK.T.(ee -wT)TORRASAE PTL *OT)N '[KsK,2 or -tor we }F33 =]T =(Ki Ke -K2Ks)-y (T,(Ki -K2K3K.)+Td,'HKiwK3LcA ; A 2 ibd x (1 -w*T,Ty) pf oti |!7 mu?(KyKo(KiXs -K2Ks)+Xi -Kak2Ky =w*Tdo Ky,KiT.37 Doon |x (Ty +Ty) P_oo!bi:pigples :pi Dae Taam|3 plaid esl =||£3.22 ELECTRIC 38 i |{Terene |-_--| || K;afFyu=]=(Kike -K2Ks)-w(T,(Ki -KaKaKy)+nae KiKs)|Ty B } x (T,+Ty) +{K3K,(Kiks -K2Ks)+Ky -K2K3Ky -w*Tde'K,KT} -x<(l-wT Ty) cece ccc escccccceers (25) ue Since Ec.(22)to (25)are very complicatec,assume -=2d G =to check t effects due coGays)K,and Gogg (8)K,to check he fects ?ss. H Eq.(23)and (25)can be rearrangec by; Fa,=1l +KK,(Ke +K2K,)! F32 =Td,'K;eee (25) F33 =Ky -Kik3K,a K 3K (Ki Kg -K2Ks) Fay,=Tdo'Kika Since the term comprising KE of F3.1 and Fis is large es compared with other terms in Eq.(26),let's obtain x," and D™by using Eq.(27). '\ --_-_-!Pai =K:K (Ks +K2K )| Dig e i cre (27) 2 bs Fes =KiKi (Kike -aks) ft 4 °:' dd i;}Date |Name ||-i ri ail -,1 bd "Fmd momo .one breve}||Farsi ELECTRIC i 39 ca Traces |---!:.<-|: an :Seto sK37K.(Ke +K2K,)(Kikes -K2ks)+w?KiTdo'?K3"Ki"=wee.(28) K3?K,?(Ky +K2K,)?+w*Td,'*k;? WeTGo 'K2K3 °K,Dp"= K3°K.?(Ke +K2K,)?+w?Td,'?K;? (Kik,+Ks)wee e eee ee (29) Ec.(28)and (29)more or less differ from actual equations, because they are formulerized for the purpose of checking _the outline. (i)Synchronizing torsue In the normal state (w =0),Ec.(28)becomes; wom =KiKs -K2ks . Ki (w=0)Ke =K2k,-a eeeeee (30) The synchronization force increases when Ks is negative.However,when AVR is provided,we obtain Eq.(31)from Eq.(12)and (17). .wt .4 _Ki +Ki (w=0)7 Ky It should be noted carefully that the synchronization force cecreases when K,increases in this case. (ii)Damping torque Let's consider the numerator in Eq.(29). eo Poi We can keep the damping torcue negative bv Do | : ; 3 Ki K,=Ks >0 ' 2).!even if Ks becomes necative.poe Go71 fe tS] oan \:i}|Date |Name bit |fone ==Fei ELESCTRIS |40 !ot 1 . 1 H ' | ' i Treced !_| v 1iAlteration|cime I _-Mtl #'(iii)PSS setting st 1 +ST.STL Pl+ST,i+sty X 1+sTyAssumekK be the PSS function. When each constant is large,the synchronizing torgue and damping torque change as outlined in the follewing "table,although this change diziers depending upon 9thewvalue. :oa .,!Synchronizing torgue |Damping torque Ks Small |Large -.' Tr Larce Large ty Large Large Ti Large Small Ty |Small Large It is,therefore,necessary to set PSS in such a manner as to increase the damping tcercue without changing the synchronizing torque noticeably. Since Eq.(22)to (25)are analytical equations in the single machine infinite system,the multisle Machine system simulation must be executed to compensate the above constants when these ecuations apply to actual systems.PeteaeeeC0r8asee:eeemywaaneensasmeesName 4 Risbo6eelVT TD2FoEEGEOROERAED -e iUeeeINaus Win 9 AD ma wise t-)atrbestWEREL)TAUUINED!STicecenarcn dba yt MAN ue a det ul 44 LD EE C3 2 eta ta "thy Sect HHUHEUTE REELED EA 72SECaMnTGRIELARSSSECTETTRRAGHATAGOCKACHKEELpdtbbetabtdista EE LG :a HASEVATEUAUTARTRETEAHUTT TTT4:if RENABRGSRENE iledotebela byl epurtan ) eed pielnate1kH '!-¢--on--e<---}t-EEwefe=»memten{ ---SF5P+=>-<"Lxir.tz2«%et-B-PAi_rt<-+4Gaf33x.faazinm=«>--abPa=--F=a>,- LPyRy)ee!m<<.=L;See,eee .FnetevmehioeendPeonweSEnennnahe-"eoPert&>aemrnes£.areba.Yntaeepee:bnReaweet.Pam UGY Gwar}2 Speeat=Peek laste.>Tevet otis-"ververiress*)+aoeaue. ROeSPPE.”titi ELECTRIC automatic Voltage RegulatorynchronousGenerator Fad foe a to wy ry rtLeeree A<AsozNT>MA osas PTesrSS:Fas settee ee! =ees = 2 Features B The dimensional units are standardized and functional elements are arranged in a draw-out type unit of speicific dimensions.- =For the convenience of maintenance and adjustments,the draw-out type unit is provided with check terminais on the front panel to check the setter's the operation and the voltage waveform. ®Inthe analog circuit of the functional unit,a high performance linear IC is used and in the digital circuit,a low noise and high reliability digital IC is used. =The main control part is on two printed boards.The structure is simple,and maintenance is easy. w The automatic voltage regulator is free from trouble caused by poor contact,etc.,since the voltage setter (90R)uses an electronic counter and D/A converter which have no sliding parts. 8 Since variation in the firing angle of each thyristor caused by frequency fluctuation is automatically compensated for,a permanent magnet generator (PMG)or tachometer generator (TG)need not be used. @ The initial excitation is enough at up to 20%of the rated voltage.The OC source capacity (battery)for initial excitation can be reduced. ®The AVR has a restriction circuit for the leading/lagging reactive power and the generator can be safely operated within the allowable leading/lagging reactive limit of the generator. @ ADOCOC converter is used for the control power source.DC source with battery,which is the most stable energy source in the stations,is used as the contro!power source. @ The following are prepared as options. *Manual control unit with automatic follow-up circuit. *Power system stabilizing unit. *Reactive power control unit. *Abackup control power source can also be provided. General Information The Fuji standard-type AVR has the following two different exciting functions. @ Thyristor exciting system (SSR-100} B®Brushless exciting system (SSR-150)roam||||/5 oe , Bebe °Ff=re:Ew:aa-.@-.2 @:e¥.se:r@:PssactTite.ss o @..c .282@::@:"2*3°..e°SePoPe td0'weeccncoesaeeessonvewee ©E6UE8eseeveseseepeeeneeee0D. |Thyristor Excitation System The basic layout is shown in Fig.1.The terminal voitage of a generator is applied to the voltage detector through the cross current compensator.The detected signal from voltage detector is compared with the setting value of the voltage setter (90R), and the difference is computed by the voltage regulator,The voltage regulator is a proportional and integrating regulator (PI). Optimum gain is taken by the P-action,and the offset error is eased by the I-action, Therefore the response is quick and the system has no offset error.The generator voitage is raised smoothly up to the set value of the SOR by the starting setter after the voltage is built to 20%by the initial flashing.(100%=rated voltage). The starting setter is made of an integrated circuit and is connected to the input circuit of the voltage requiator.With this circuit,the DC power source capacity for initial flashing can be reduced,and the initial flashing can be done without the overshoot of terminal voltage. The field current is compared with the If max.setter. If the field current exceeds the setting value,the main field current regulator operates and limits the output of the voltage regulator,And the generator can be safely operated within the allowable fieid current. The firing angle regulator converts the output signal of the voltage regulator into the thyristor gate pulse.The firing angle regulator adjusts the firing angie of the thyristor rectifier in accordance with output signal of the voltage regulator.Even in :case of a large frequency change,including load rejection,the firing angie correction for the frequency change is included. Neither a PMG nor a tacho-generator is necessary. Fig.1 Block diagram of the thyristor excitation system A printed circuit board A printed circuit board ae are SSBeteresesPTliaoOe. $":]Reactive power [}:i Cross current<_]restricting unit [-compensator Firing angie controiier erTatSenta Fb+wer ge!"Ap mepes for Set Main fieid current regulator battery Exciting transformer a dn Aux.CT 41 Field circuit breaker - if 3 ;y 31 se £ 6 ;ans(<)a £££ Oischarge 3 Thyristor resistor 41) --_/ Station Brushless Excita**on System The basic layout is shown in Fig.2.The voltage setter,voltage detector,voltage reguiator and firing angle regulator are the same as those in the AVR for thyristor excitation system. In the brushless excitation system,the response in the control system is generally detayed because of the AC exciter in comparison with the thyristor excitation system. To cope with this delay in the response,a field current regulator and derivative circuit with a dead band are used in this system. The field current regulator constitutes the minor control loop with a feedback signal of the field current.The delay in the AC exciter is compensated by the gain and I-action to this regulator. The derivative circuit with the dead band functions for a quicker response to a drastic voltage change and consists of an incomplete derivative circuit with a dead band.The derivative circuit with the dead band does not respond to a slight voltage change during ordinary operation,but in the event the voltage changes drastically,more than 3%,it gives the voltage regulator a signal which differentiates the changed value,and restores the voltage quicker, Fig.2 Block diagram of the brushless excitation system A printed circuit board eee©petemeet!wocestee " .A printed circuit boardor||Pesan :t-s $Reactive powe l Cross current :2 restricting unit:compensator '$ -- '>CT + «=ca?eee :eet Oe 2, }se [Main Tred}«2°y eycurrent ,we .:Exciting :'regulator om Te .transformer a H:&ot <Aux.CT s = := Fy 41 Field circuit breaker ia 4 H --7Se:{|[eeG€:)=A |*££ Discharge Thyrnstor resistor 41 - Station battery Basic Unit Principles of Operation 4.Cross Current Compensation and Voltage Detection The droop characteristics must be prepared for the parallel running of synchronous machines.In this case,the droopcharacteristicisperformedbythecrosscurrentcompensation circuit as follows: The connection for the cross current compensation circuit and its vector diagram are shown in Fig.3.The CT secondary current of phase t and r are added to the PT secondary voltage of phase u and w through resistor R as shown in Fig.3 (a). As shown in Fig.3 (b),the DC voltage,produced by rectifying the above vector added to the voltage in the 3-phase full-wave bridge,corresponds to the area of AU,V,W,at the generator power factor =1.0 as shown in Fig.3 (b),and it corresponds to the area of AU',V,W',at the power factor =O (lag).At the generator power factor (lag),the triangle area becomes larger such as from AU,,V,W,to AU',V,W',.This means that the larger lagging power factor is the same as higher terminal voltage.The drooping characteristic is formed by this circuit. (In case of a leading power factor,the triangle area becomes smaller.) There are various methods for creating the drooping characteristic.However,in this method,as shown in the vector Fig.3 (b),the triangle always remains a regular triangle irrespective of the generator power factor.Therefore,the ripple of the DC voltage after the rectification in the 3-phase full-wave bridge is the same.The same ripple is favorable for the subsequent filtering. 2.Voltage Setter A digital electronic counter is used for the voltage setrer of this AVR.An electronic logic computation is made for the setting change and unlike the conventional motor driven resistot setter,this AVR voltage setter has no sliding mechanical contact. Accordingly,no troubles will be caused by poor contact. The setting value is counted and memorized with the digital counter when a signal up or down is given from the outside. 'The counter memorizes standard puises in proportion to the up or down signal duration and the memorized vaiue is converted to an analog signal by the D/A converter.In the voltage setter,the standard operating time from 80%to 110%is 45 seconds (fixed},and the accuracy is 0.11%(in case of a setting ragne 30%from 80%to 110%). With this kind of electronic setter,when the control power source is lost,the setting value cannot be maintained. Therefore,a countermeasure is used with this setter so the setting value will be maintained for two seconds afte. loss of electric power.In case of initial reset and/or after a long power failure,the setter is reset at the lowest setting value (80% of rated voltage is standard).The block diagram is shown in Fig.4. 3.Voltage Regulator This voltage regulator is a P!regulator.Proportional gain (G) and reset time (T!)are defined as shown in Fig.5. Fig.3 Cross current compensation RST t pToy F (a)Circuit connectiondiagram ' (b)Vector diagram for (a) Fig.4 Voltage setter action block diagram -.UpJoOo Logic wt Reversible DIA Voltage counter and f=P=settingToFELhemoryconverter|SonalDown Standard Dulse trans- mutter (quartz) Fig.S Action of Pi regulator Ov Ga Bt.1 frimes)rte c,|0Je @:position of potentiometer Ro Ri Ro 'a0 at OV side.a@ 1 at amolifierSettingrerminalsideOetection T,*RAt-C,[seconds] | °J i OopeeeetemeeeOyMetMeyadF308adPeeeekeeeaoySBe:emceetne4.Firing Angle Regulator The firing angle regulator convertsthe control signal from the voltage regulator into a pulse signal for firing.The control of the firing angle is carried out as shown in Fig,6. Fig.7 (a)shows the AC voltage (broken line)and the synchronous signal voltage (full line).In the 3-phase bridgeconnection,the point lagging 30°behind the AC voltage isdefinedbythefiringangleO°(a=0°).Fig.7 (b)shows a sawtooth wave as the standard synchronous signal and the control signal (chain line)from the voltage regulator.As shown in Fig.6,the firing pulse is produced at these cross points. Therefore,when the control signal from the voitage regulator changes,the cross points with the sawtooth wave are shifted, and the pulse changes the firing angle.Auxiliary functions are provided so that these relations can be retained even if the frequency should change widely. Fig.7 (a)and (b)show the relation of the pulse and the OC output voltage.In case of a uniform thyristor bridge,the pulse is a dual pulse. Fig.7 (a)Firing angie pulse of the non-uniform bridge U phase f n Fig.6 Firing angle regulator control AC voltage at Synchronousthyristorsignal 'dla0.- -'=rd "wy Av(ars a ¢ a on '..*. >ca we iad (b)t :Control ; 'signal ' + (elt h Fig.7 (b)Firing angle pulse of the uniform thyristor bridge 5.Starting Setter The starting setter is a device for establishing generator voltage without overshooting-ehe setting value of 90R after the field flashing.The operation is shown in Fig.8. As shown in Fig.8 the output Vis of the starting setter is set to 20%at the beginning of fieid flashing when the "use” contact is ON,and raised gradually to a value equivalent to 80% voltage.This raising time is set at about 5 seconds,On the other hand,the voltage setting range of voltage setter (SOR)is 80-110%.Therefore,when the voltage setter starts at the lowest limit value of SOR,the output Vis of the starting setter is minimum setting value of SOR.The AVR is put into operation after the voltage has been established up to 20%by the field flashing,and the voltage rises up to 80%in 5 seconds with the rise of Vis.If this rising time is longer than the time constant of the generator field (Tdo')there is no overshoot at the time of generator start. After the start has been completed,it is possible to set the voltage to 80-110%(80 +(O 30%))by operating 9OR. 6.Derivative Circuit with Dead Band This derivative circuit acts on the generator field with a large gain when the voltage deviation is larger than 3%.This circuit in only applicable to the brusheless excitation system.The operation is shown in Fig.9. Fig.9 (a)shows the diagram of the derivative circuit with the dead band.Fig.9 (b)shows the signal activity.When the voltage fluctuates beyond the dead band,a signal is given to _the voltage regulator,and the excitation current is quickly raised or lowered corresponding to the signal. Fig.8 Operation of starting setter To thyristor gate Voltage regulator Initial setter Fig.9 Operation of the derivative circuit with dead band To voltage regulator (a) Voltage /detection!-|S /| (Derivative)(Dead band) (b) Voltage change r-sf Ocead band Derivative outputh---te ----------an aa Output of dead L. band ,Yo fp TS PEILEORES TPE DCS AE AE CATR ASAE DE ARBRE,ob RN eAErana 7.Firing Angie Regulator (F.A.R.)Output Pulse Monitor Circuit For all 6 phases of F.A.R.output pulse,a time is used to monitor the period when pulse is turned ON or OFF. In case a fauit occurs,a fault signal is output to the external sequence circuit. &Frequency Drop Compensator (V/F Compensation) Frequency drop compensator protects the main transformer from overexcitation by reducing the generator voltage in proportion to the frequency at a frequency drop (before circuit breaker closing). 9.Field Current Limiting Circuit This circuit is used for monitoring as well as limiting the field current when it abnormally increases due to some system faults. The field current is induced in the rectifier through ACCT and converted to a voltage proportional to the magnitude of the field current. This converted voltage is compared with the setting value determined by the setting device If max.If this detected voltage exceeds the setting value,the main field current regulator operates and limits the output of the P!controller.This main field current requiator has a delayed action so as not to disturb the forced excitation. 10.Lesding/Lagging Reactive Power Restriction This device is designed to carry out limiting on the leading and lagging sides of the generator capability curve as shown in Fig.10. Operation of the generator exceeding its capability curve due to changes in the power system voltage or malfunction of the voltage setting device will result in overheating in the rotor winding or overheating of the stator end iron core.such extreme case,that exceeds the limit for stabilized operation > will lead to step out and damage to the generator and system. If this limit should be exceeded the voitage setting device is automatically controlled in such a manner to keep the generator Var current within the predetermined limits.Since this control function is provided with an appropriate time jag,dynamic stability of the generator is assured. This unit is equipped with a setting lever.Table 1 lists settingspecifications. Tablet "=28..'Applications ;,"*{Hydraulic power plant |Thermal power piant Operaitng current |!#40 to 100%40 to 100% setting te 40 to 100%10 to 60% aoo%rated [a 60 to 90°60 to 90° ¥e 60 to.90°60 to 90° Fig.10 Reactive load Simiting characteristics Limue of reactive load (leading) Generator capability curve Rated outout of generator Limit of reactive load (legging! Q Var iead le Q tal Q Ver tag Optional Un..s The following optional units are available upon request. ¢Manual control unit_with automatic follow-up circuit *Line charge circuit *Reactive power control unit ¢Line drop compensator *Power system stabilizing unit These components are shown in Fig.11. Fig.11 Optional units PT peoeoc moe om mewniCrosscurrenti_ Voitage :I Votuge |!T Firing angie |° yeompensatory [|detector|Jt {fevulator|tcontrotier|]Sct fw Var |3 Line drop (O teterknte!_ conv!jeonv.ompensator 'voltage;Limiter A printed board '(SOR)3EEPathkeaapRTOSTFPaesposet=ower system=er2]stabilizer |Line change =-=RAISE SIGNAL unit mn "=7""]Reactive power[7Eo|ontrotler :LOWER SIGNAL =" eo ee {A printed boardAprintedboapeete:TES, 5 >° Exciting eee en aT aetransformernotePeeTPater an ee OU DhE Nate tee oe -"pe: |q .Se tet -(ata)Field current b hom detector =- =q oe abe 1 Thyristor _Au -_--. af.-90M RAISE/LOWE! 'Menu...!'R RAISE/LOW, Peee.|"*value of SOM.It means that manual an,OettnAEE!Steayat:Principles of Operation 1,Manual Contro!Unit with Automatic Follow-up Circuit Manual control loop is provided-asa back-up system for the AVR.The setting device 90M is always followed up to have nearly the same output value as the automatic regulating loop. Output signal of manual controi loop is obtained from comparing circuit between the actual field current and setting control is used as an "automatic field current controller”and this is better than a complete open loop manual control. The automatic foltow-up controller operates to make 90M match the actual field current when it is in automatic operating mode,and operates to make 9OR match the actual generator terminal voltage when it is in operating mode. Regardless of the operating mode,the input signal of the firing angie controller of each control loop is always corresponding. 2.Line Charge Circuit The line charge circuit is designed to increase generator terminal voltage smoothly from approx.10 percent rated voitage up to the full rated voltage. The line charge empioys the automatic field current regulating system (ACR system),and its configuration is shown in Fig.12. Setting device @ is used as voltage setting device (SOR). .Setting device @ is a field current setting device for linechargingandisstackedwithsettingdevice@. The ACR detects and amplifies the deviation between the setting value and detected value of field current,and its output is connected to the limiter of the P-}controtler (voltage regulator}.Therefore,the output of the P-!t controller is limited to the value determined by the setting device ©. The characteristics of the setting devices @ and Z are as follows; in the low voltage area that is used for line charging as shown in Fig.13,the exciting current is limited to a value determined by the setting device @. When the stacked setting devices @ and ©)are at lower positions {or higher positions)than the intersecting point of the two straight lines,generator terminal voltage is Jimited by the value (or adjusted by the value}which is determined by setting device @ (or by setting device (). Therefore,as the stacked setting devices @ and @)are moved fram lower to higher positions,generator terminal voitage increases smoothly along the lower straight line. Fig.12 Line charging circuit PT Cross current compensator Voltage133-2 3reguiator Limiter device @a Stacked deview (2)«" Field current wreThyristor Main generator .-"Pe *aay ete (>oe "Line charge unit | Fig.13 Characteristics of line charging circuit Setting device (2)-GeneratorvoltagePosition of setting device €f 3.Reactive Power Control Unit The reactive power control is classified into the following states: NQeA Qesa 2)Q=B-P Q=+B-P 3)Q=AtB-P Q=+A+B-P Q=A+B-P Q=tAtB-P (NOTE)Q:reactive power . +:lagging A.B:setting value (0 1) In Control State 1),reactive power is controlled constantly irrespective of active power...AQR in Control State 2),reactive power is controlled according to active power,and power-factor is controlled constantly ... APfR Control State 3)involves the functions of both 1)and 2).In case of setting value "A”=0,the controller can be used as APFR. In case of "B”=0,the controller can be used as AQR.It is also possible to control reactive power according to the character- istic of generator capability curve by setting "A”and "B'”' properly. The control characteristic is shown in Fig.14. Control is carried out intermittently by the interrupter.The controller produces the raising and lowering instructions by pulse.The control deviation is controlled in the zone.The fundamental block-diagram is shown in Fig.15 and an example of control is shown in Fig.16. P:active power -:leading Fundamental block diagram Deed zone A Comperator -- pone Output inter-(raisingrupterJULinstruction) Comparetor --P=Output(lowering instruction) Fig.14 AQR (APR)control characteristic Fig.15 Pp Pp QeA QeaA Q=-sBpP Q=epPp Qllead)State 1 Qllag)Qliesd)State 2 Qlleg) PQ=A-aP p Q-a+BP Q A+ep |QeA-8P Fig.16 Setting veiue Qllead)Qliag)Aliead)Qltag) State 3 Example of control Ocead zone A !1"4 :SSD.MM MANLireasCOALwoownTime4 1 4 Oead zone 8 4.Line Drop Compensation Line impedance exists between generator and infinite bus as shown in Fig.17 (a)"Connectiorrot generator and infinite bus” Therefore,the reactive power can be fed by the generator only when the infinite bus voltage (Vg)is less than generator terminal voltage (V2). A setting value proportional to the variation of reactive power is added to the setting value of voitage setting device (90R) .using the line drop compensator. So,the larger the generator output,the larger the AVR setting voltage. However,in case of load rejection,this compensating circuit is separated from the line in order to minimize the voltage rise. 5.Power System Stabilizer (PSS) The PSS is mainly used to prevent negative damping phenom- ena (decrease of damping torque)in the generator contro! system when generator output is large and the power factor is poor,in order to increase the system stability. The PSS uses active power as an input signal,and consists of the following three sections. *Signal reset section (derivation circuit with dead band) which detects power fluctuation. *Phase angle regulator which computes an optimum phase corresponding to the system and generator constants. *Gain regulator which computes an optimum signal level. The output signal of PSS is supplied to the voltage regulator of the AVR. Fig.17 (a)Configuration of singie machine against Fig.17 (c)Characteristic of line drop compensation infinite bus Gen.terminal H veLILLLLLLLLLNe"ee a Line impedance Setting(lag)Value by compensator Lee eee "<<vt Setting ||aveetvalueVref!' Reactive power(Q:tag) Fig.17 (b)Line drop compensating circuit $Voltage -|.$$detector > AVR --- N.FyLinedrops compensator é 9 Standard Specifications (1)Voltage settingrange 80 to 110% --(100%=rated voltage) (2)Drooping rate 0 to 15% (3)Signal level t10V DC . (4)Accuracy of control Less than 0.5% (5)Power source DC 100/110V (6)Power consumption Less than 200VA Firing power supply for thyristor is not included. (7)Permissible voltage . variation -15 to +10% (8)Permissible frequency variation -3 to +2Hz (50/60Hz) (9)Permissibie ambient temperature 10 to +40°C (10)Derivative circuit with dead band Dead band 3 to 5% Gain 10 to 100%(percentage to detected voltage) Derivative time 1.0 sec. (11)Pt controlier P 5 to 100% I 0.1 to 2.0 sec. (12)Unit integrator integrating time 1 to 6 sec. Manufacturing Specifications The standard AVR unit is supplied in accordance with the manufacturing specifications shown below: ®@ Paint finish of cubicles Front face:Munsell 5 Y 7/1 Rear face:Munsell §Y 7/1 @ Wiring specifications Wiring system:Combination of duct wiring and bundle wiring systems Wire specification:Wire conforms to either JIS C3316 (KIV)or JIS C3307 (IV).The power supply circuit, PT,CT secondary circuit,and control circuit use 2mm? stranded wire.The signal circuit use 0.75mm?stranded wire. Color coding of wire Main circuit:Yellow or black AC,DC control circuit:Yellow PT,CT secondary circuit:Yellow Earth circuit:Green Fig.18 Connection types Crimp-connected portion tasulation cap Soldered portion Wire a,Ss 2 | Insulation sieeve (transparent) Color coding for polarity and phase OC Positive polarity:Red Negative polarity:Biue .AC Ist phase:Red,2nd phase:White,3rd phase:SlueZerophaseandneutralphase:Black Outline and Dimensions Front View fal H i '<----g , {Power source unit orft> Control and detection gj24ow wr Control i L =a" 600 Inside Front View cuA I A-A'Section -S-- pee ©eee2ote ed 1160 1220 =-|hoo a Fuji Electric Co.Ltd. 12-1 Yurakucho 1-chome.Chiyoda-ku.Tokyo.100 Japan Phone Tokyo 211-7111 Telex J22331 FUJIELE ( STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREETAENGLEWOOD,COLORADO 80111 ADORESS ALL CORRESPONDENCE TO P.O.BOX $406,DENVER,COLORADO 80217-5406 W.U.TWX.910 935-0105 TELEPHONE:303 741.7700 FAX.303-741-7670 WU.TELEX:45-4401 RCA TELEX:28925!303-741-7671 BOSTON wew YORK CHATTANOOGA PORTLAND ME CHERRY MILL NW PORTLAND OR cuicacoge RICHLAND WA OauLas RICHMOND VA OENVER San FRANCISCO fT LAVOEROALE TAMPA nOUSTON WASHINGTON OC July 12,1990 Mr.D.R.Eberle J.0.No.19239.26 Project Manager WP26A Alaska Energy Authority SWEC/AEA/2599 701 East Tudor Rd. Anchorage,AK 99503 SYSTEM STABILITY SOLUTIONS BRADLEY LAKE HYDROELECTRIC PROJECT We are continuing to review the work done by our subcontractor Power Technologies,Inc.(PTI)for technical adequacy and feasibility of implementation of proposed Kenai transmission system stability solutions as requested by the Technical Coordination Subcommittee (TCS).Although our review indicates technical feasibility of the proposed solutions,it has raised several concerns regarding the approach and solutions being proposed in an attempt to comply with the stringent criteria set by the TCS.PTI's method has been to find solutions which meet the TCS's criteria under the constraint that no new lines are constructed or existing lines upgraded.This has led to solutions that are very complicated,require sophisticated operation and maintenance,and could be of questionable reliability. Reliability in the transmission of power has two components,capacity and reliability (adequacy and security as defined by the North American Electric Reliability Council -NERC).These are often considered separately.Most utilities use what is commonly called an "n-1"criteria for addressing reliability (security).That is,the bulk transmission system must be able to survive the failure of any circuit and still operate in an adequate manner.This means at least two transmission paths must be provided between any two points in the system.It is recognized and accepted that when two paths are not provided the n-l criteria is not met and a single contingency failure will cause an outage or separation of portions of the system.It must be recognized that it may not be physically or economically possible to design portions of the system to n-l criteria standards.Under such situations,most utilities relax the criteria or reduce their expectations of the system. _- isty >STONE &WEBSTER:yyy ( STONE &WEBSTER ENGINEERING CORPORATION 5500 SOUTH QUEBEC STREETAENGLEWOOD,COLORADO 80111 ADORESS ALL CORRESPONDENCE TO P.O BOX $406,DENVER.COLORADO 80237-3406WUTELEX:east Rea TecEe 3332817700 FAK Baral Jergratranooea romTiaNo wesesfPeewaaesasseeneeoeOuUSTONMWasnenGTonOc - July 12,1990 Mr.D.R.Eberle 3.0.No.19239.26 Project Manager WP26A Alaska Energy Authority SWEC/AEA/2599 701 East Tudor Rd. Anchorage,AK 99503 SYSTEM STABILITY SOLUTIONS BRADLEY LAKEHYDROELECTRICPROJECT We are continuing to review the work done by our subcontractor Power Technologies,Inc.(PTI)for technical adequacyandfeasibilityof implementation of proposed Kenai transmission system stability solutions as requested by the Technical Coordination Subcommittee (TCS).Although our review indicates technical feasibility of the proposed solutions,it has raised several concerns regarding the approach and solutions being proposed in an attempt to comply with the stringent criteria set by the TCS.PTI''s method has been to find solutions which meet the TCS's criteria under the constraint that no new lines are constructed or existing lines upgraded.This has led to solutions that are very complicated,require sophisticated operation and maintenance,and could be of questionable reliability. Reliability in the transmission of power has two components,capacity and reliability (adequacy and security as defined by the North American Electric Reliability Council -NERC).These are often considered separately.Most utilities use what is commonly called an ""n-1"criteria for addressing reliability (security).That is,the buik transmission system must be able to survive the failure of any circuit and still operate in an adequate manner.This means at least two transmission paths must be provided between any two points in the system.It is recognized and accepted that when two paths are not provided the n-l criteria is not met and a single contingency failure will cause an outage or separation of portions of the system.It must be recognized that it may not be physically or economically possible to design portions of the system to n-l criteria standards.Under such situations,most utilities relaxthecriteriaorreducetheirexpectationsofthesysten. _-SN " anys STONE&WEBSTER «sveoe-----oe Mr.D.R.Eberle July 11,1990 Page 2 The transfer capacity (adequacy)of any transmission path is limited by its weakest parallel link.For the existing Quartz Creek to Anchorage intertie,a radial system,the first contingency could be a trip of this single line which would reduce power transfer to zero.In the case of the Bradley Lake to Soldotna segment,the power transfer capacity (adequacy)would be the capacity of the existing Sterling Highway line (ie.the first failure could be the new Bradley to Soldotna line leaving only the older,longer,lower capacity Sterling Highway line to carry the required power). In 1988,Southern Electric International (SEI)was commissioned by the TCS to determine how much power could be exported from the Kenai,and what system changes would be needed to provide increased export with the addition of Bradley Lake.Their conclusion was the addition of a parallel 230 kV line from Soldotna to Anchorage.PTI was subsequently commissioned by AEA,separately from Stone &Webster's scope,to determine if Bradley Power could be exported to Anchorage without the construction of an additional Kenai to Anchorage intertie. It is clear from these studies that without some form of improvements,the transmission system on the Kenai and the existing Kenai to Anchorage intertie would not be capable of handling 120 MW of Bradley power or of exporting 75 MW to Anchorage,without exceeding the TCS's criteria and prudent operating limits of both capacity and reliability.In addition,there would also be large line losses. Further,PTI's studies concluded that it was possible to export 70 MW of Bradley Lake power to Anchorage,with stability improvements to the existing and planned Kenai System.SVS,series capacitors,braking resistors,and forced deflector runback were proposed.PTI's study also indicated that construction of the additional Kenai to Anchorage intertie did not alleviate the need for some of the proposed equipment. In early 1989,AEA directed Stone and Webster to retain PTI as a subcontractor to perform final system studies and to design and implement the stability solutions previously proposed by PTI.The objective was to design improvements which would enable 75 MW export from the Kenai in the abscence of a new Kenai Anchorage intertie.Several key studies have been performed towards achieving this objective,some are currently underway,and others remain to be done. This approach to increasing transmission capability to enhance the use of Bradley power is not typical.Transmission of power near the limits of the transmission system leads to considerations of transient and steady state stability.Stone and Webster's (and PTI's)preferred,and a more normal,approach to the question of power transmission limits in the Kenai area would be: Mr.D.R.Eberle July 11,1990 Page 3 1)Review Utilization of the existing System -The limitations and reliability of the existing system without any improvements would be evaluated to determine if they are acceptable.This would create a value based criteria for enhancements that is cost sensitive.In the case under study,the TCS has indicated that the existing system limitations would not be acceptable, and have established criteria to be met.The TCS criteria does not provide for cost sensitivity.In essence,it is a set of conditions to be met. 2)Transmission Line Improvements -New transmission lines and/or upgrading of existing lines can increase transmission capacity and reliability to a greater extent than any other solution.Evaluation of each segment of the Kenai transmission system for possible transmission line improvement or additions, and their benefits would provide additional cost sensitive information. 3)Add_Static Var System (SVS)-Static var systems help control voltage thus improving steady state and transient power transfer capability.They can also contribute to damping of oscillations following a disturbance.SVS's can be coupled with fixed and switched shunt capacitors to provide an even larger margin of control.Evaluation of the benefits and costs of SVSs would be considered as additions or alternatives to 1 and 2 above. 4)Add_Series Capacitors -Series capacitors increase the steady state and transient power transfer capability by decreasing the electrical impedance of the line they are on.Due to many potential adverse system problems, these would be considered a last resort solution. In contrast to the above approach,PTI and SWEC have been asked to determine what solutions are needed to meet the criteria established by the TCS without consideration of Items 1 and 2 above.This has led to the proposal for braking resistors,forced deflector runback,and SVS and series capacitators. The recent braking resistor and deflector triggering study by PTI demonstrated that an extremely sophisticated sensing and control scheme will be required to implement the proposed solution.This sophisticated sensing and control scheme, along with the proposed remedial actions are the direct result of the very stringent design criteria and high expectations placed on the Kenai transmission system and Bradley Lake by the TCS.We are concerned that the highly sophisticated solutions proposed by PTI will have problems with design, implementation,and continued reliable operation.We have discussed these issues with PTI and they have the same concerns.We question whether the construction and maintenance costs,as well as the risk of failure of these solutions can be justified by the increase in performance provided. Mr.D.R.Eberle July 11,1990 Page 4 Because of these concerns,we recommend that the following be considered by AEA and the TCS. 1)Reexamine the performance criteria established by the TCS.We believe that relaxing some of the criteria established by the TCS can significantly reduce the equipment needed and the complexity of some of the control schemes.The present criteria for a 61.5Hz over-frequency limit,auto reclosing of some lines,and 120 MW output from Bradley Lake necessitate complicated brake resistor and deflector operation. The following could be achieved if some of the criteria are changed: a) b) c) In a) 90 MW (approximate)generation capability at Bradley with full reliability (ie.the system remains stable following faults which do not island the Kenai). 120 MW emergency generation capability at Bradley (ie.steady state stable and within voltage and line loading limits but unable to tolerate severe faults). 75 MW Kenai export capability at Daves Creek. order to do this the following changes need to be made in the criteria: The Kenai over frequency criteria has to be raised to allow momentary frequency excursions up to 63 Hz.A plot is attached showing the required over-frequency limit.The Tesoro over-frequency relay would have to be reset accordingly. It is difficult to provide a hydroelectric based system that can meet tight system frequency requirements.With the use of Pelton type turbines at Bradley Lake,frequency response is better than with some other types of turbines.However,to meet the frequency requirements established by the TCS,several unusual solutions have been proposed.They are:direct deflector runback (control of the deflectors independent of normal governor action),speed control by the deflectors rather than the needles,and braking resistors. Current TCS design criteria limit Kenai over-frequency to 61.5 Hz.This limit was established primarily due to the 61.5 Hz trip point used on the Tesoro refinery over-frequency relaying.HEA,after discussions with the Tesoro refinery,has indicated that Tesoro does not have any process or equipment that would be harmed by letting the frequency momentarily approach 63 Hz.Further,HEA has indicated a desire to avoid tripping of load during over-frequency excursions of reasonable magnitude and duration. To them a 63 Hz limit,for short time periods,is acceptable.HEA recognizes that tripping the Tesoro load during over-frequency conditions would only compound the problem and jeopardize service to other loads. Mr.D.R.Eberle July 11,1990 Page 5 b)High speed,auto reclosing on the Daves Creek-Lawing,Daves Creek-Quartz Creek and Quartz Creek-Soldotna 115 kV lines needs to be disabled. High speed auto reclosing following faults is a common practice on large utility systems where system strength and stability margins are significant.In the case of the Kenai system with the proposed generation and power transfer scenarios,the TCS's requirement to survive high speed auto reclosing of some lines creates a reliability risk and leads to the need for the braking resistors and deflector runback.Since Chugach Electric Association (CEA)has a supervisory control system,breakers could be reclosed under supervisory control once the initial effects of a disturbance have settled.Such an operating practice would not unduly extend the outage duration of loads affected by a fault.Many loads would not come back under high speed reclosing (eg.motors,compressors under load,etc.)anyway.In either case,if the fault persists,the load would be out until the cause of the fault is corrected. These changes (frequency and auto-reclosing requirements)would most likely eliminate the braking resistor,or greatly simplify its use,and will reduce the need and complication of the deflector runback.Power system stabilizers on each Bradley Lake unit,the Soldotna SVS and series Capacitors,or two SVS's,would still be needed. 2)Utilize two SVS instead of series capacitors. Sufficient data in order to complete the subsynchronous resonance (SSR) _studies has yet to be made available by General Electric.If the data is not available for the studies,they can not be completed.There are three alternatives.One is to utilize series capacitors without completing the studies.However,due to the risk of equipment damage this alternative is not recommended.The second is to have General Electric perform the SSR studies under subcontract to AEA,SWEC or PTI.This will result in a significant increase in cost,and does not provide independent verification of results.There is also the risk that the studies will show that series capacitors are not feasible anyway. The third alternative is to eliminate the series capacitors and use two SVSs. The use of two SVSs is more expensive than one SVS and series capacitors. However,series capacitors have several disadvantages.The series capacitors, due to the SSR problem,would require that whenever significant changes are made to the system;new or restructured lines,generators,etc.,SSR studies will have to be performed in order to reevaluate impacts.Transient voltages are a problem with series capacitors.Also,while unlikely at 115 kV,there is the potential for ferroresonance between transformers and series capacitors.We recommend the use of two SVSs instead of series capacitors and an SVS.While they have higher construction costs,we believe that SVSs may prove to be the more cost effective and flexible solution in the long run. Mr.D.R.Eberle July 11,1990 Page 6 3)Transmission line upgrades and new construction,should be reviewed for their potential present and long term benefits to the system.In reviewing the system from Bradley Lake to Anchorage,we believe that there are three key segments.Bradley Lake to Soldotna,Soldotna to Quartz Creek,and Quartz Creek to Anchorage (University or International substation).To improve power transmission and_transient stability on these segments we suggest the following modifications be considered. a)Bradley Lake to Soldotna -An additional 115 kV line from Bradley Lake to Kasilof (alternatives are Bradley Junction and Soldotna).This would provide a third path for Bradley Power to Soldotna,thus increasing reliability,reducing line losses,and improving transient stability on .loss of the Bradley Lake to Soldotna line.This would eliminate the need for the southern SVS,and reduce the need for the brake resistor.The resistor is needed for faults on the Bradley Lake to Soldotna line,and the Kenai-Anchorage intertie.It could be eliminated if this line and the intertie described in 'c'below are constructed. An alternative would be to upgrade the existing Sterling Highway line. This would reduce losses but has a limited stability benefit due to its longer length.An SVS at the southern end of the Kenai would still be needed with this alternative. b)Soldotna to Quartz Creek -Convert the present 69 kV line from Soldotna to Quartz Creek to 115 kV operation.This would improve transient stability on loss of the existing 115 kV Soldotna-Quartz Creek line,and increases power transfer capability.Combined with 'c',below,this would reduce the size of the northern SVS. c)Quartz Creek to Anchorage -Build a second 115 kV or 138 kV line from Soldotna (Quartz Creek if item "b"is done)to Anchorage (International or University).This would improve power transfer,reliability,and meets the n-l criteria.Also it would reduce the need for the brake resistor, or eliminate it if "a"is done,and reduce the size of the northern SVS. Any combination of the above transmission line improvements would be beneficial.While we recognize that no commitments for new or upgraded lines have been made,any of the transmission line changes proposed above would reduce or eliminate portions of the equipment now proposed and would significantly improve performance of the Kenai transmission system.We believe that it would be prudent for the utilities at this time to at least consider the construction of these alternatives as part of their long range planning and consideration of overall system reliability. Mr.D.R.Eberle July 11,1990 Page 7 Please review our recommendations with the Technical Coordination Subcommittee. We believe that the issues we have presented in this letter and previously discussed with you should be seriously considered before commitments are made for any equipment.We would like to discuss the above at the TCS meeting scheduled for July 19. T.Critikos Project Manager TC/JBY/LW cc:HClark (PTI) 'Attachment CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska July 19,1990 TO:David Highers,General Manager VIA:Eugene N.Bjornstad,Executive Manager,evOperatingDivisionsMichaelE.Massin,Director,Engineering FROM:David W.Burlingame,Manager,Facilities engineering ff SUBJECT:Bradley Lake TCS Meeting -July 19,1990 Below is a synopsis of the above referenced meeting: abili ovement: A considerable amount of the morning session revolved around AlaskaEnergyAuthority's (AEA's)position on the proposed stability improvements.Political fallout from AEA due to recent statementsonstabilityconsiderationsrelativetocommercialoperationoftheplantwasveryapparentandattimesveryblunt.The meetingprogressedverywelldespitearockystart,however the utilitieswereleftwiththeimpressionthatAEAwouldincludethestability improvements in the project's cost,so long as the AEA felt the utilities'positions and criteria were reasonable. Generator Testing The Kenai generator test report will be available to the utilities by August 1,1990.The remaining units will be available by August 15,1990. SCADA A listing of the points to be connected to the Chugach RTU was distributed and approved. HEA Line Homer Electric Association,Inc.(HEA)stated the line from Soldotna to Bradley Junction will be completed by April 1,1991. tabilj udies After considerable debate,a list of stability cases previously presented by Chugach to assess the ability of Bradley Lake tooperatewithouttheadditionofanystabilityaidswasadoptedwith little changes. David Highers Bradley Lake TCS Meeting Notes July 19,1990 Page 2 The Committee agreed to allow tripping of Bradley Lake units in the interim fix prior to the addition of stability aids,if this wouldallowahigheroperatingpointfortheplant.It would appear unit tripping will allow the plant to operate at or above 90 MW when first commissioned. Stone &Webster Engineering Corporation (SWEC)made a formal recommendation against the use of series capacitors in the Bradley Lake area which was accepted by the committee.This means the stability solution will contain at least two SVS installations on the Kenai. SWEC also stated they would not endorse the use of the braking resistor as proposed by Power Technologies,Inc.(PTI).They felt the reliability and operating procedures were too difficult to implement and maintain. SWEC also stated they may not endorse the use of the braking resistor's use at all,even if used with a very simple trippingscheme.This may be a point of contention if the use of a brake will allow a higher operating capacity for Bradley Lake. Chugach and HEA agreed to allow the transient frequency for theKenaitogoabove61.5 Hz if no adverse effects are found by theturbinemanufacturers.Chugach's generation department is lookingintothis. The committee moved to accept a Fuji stabilizer on the governor,solongasusingitdidnotinanywayreducethecapacityoutputofBradleyLakeoverthemoreexpensivePTIorGeneralElectric(GE)stabilizer. The Committee recommended proceeding with the bidding process forthebrakingresistorconcurrentwithSWEC's review of its use and application. AEA expressed concern over how its upper management would take the recommendation to delete the use of series capacitors and proceedwithanallSVSsolution.However,coupled with the use of unit tripping its blow may be softened. David Highers Bradley Lake TCS Meeting Notes July 19,1990 Page 3 Conclusion With the use of unit tripping and possibly higher frequency excursions,it would appear Bradley Lake will be able to operate at or above 90 MW in the fall of 1991.This will result in voltage and frequency excursions in the interim that are higher than would be acceptable over a long period of time but should be acceptableintheshortterm.The stability cases requested should give an accurate representation of the system and the associated risks involved with its operation. Some of the things Chugach can do 'to lessen the risk and/or increase the capacity output of Bradley Lake are as follows: 1.Whatever we can do to expedite the reconfiguration of the University 115 kV bus should be done.There is a very goodpossibilitythiscouldbeconsideredtherestrainingfactorinBradley's ability to operate at its 90 MW capacity.It may beotherutilities'position that Chugach is responsible for thecapacitydifferenceforBradleyLakebetweenthetimeitis declared commercial and the time the bus rebuild allows the 90 MW output. 2.Continue the improvements on the 115 kV system designed forBradleyLakeoperation. Unit Testing SWEC will present a tentative schedule in August outlining thetestingperiodsandproceduresfortestingtheBradleyunits.SWECwillperformthestudiesrequiredtodeterminewhatgas-firedgenerationwillberequiredtoperformthetests. ce s I was elected Secretary and Vice-Chair of the committee,replacingMikeYerkes. DWB/pn DWB4-57 cc:B.Byrnes B.Evans D.Gropp T.Lovas R.Olson File 410 Alaska Energy Authority 2 REPORT ON LOAD ACCEPTANCE ANALYSIS BRADLEY LAKE HYDROELECTRIC PROJECT pis copy betty cH theseCopy BX , he & Prepared by STONE &WEBSTER ENGINEERING CORPORATION Denver,Colorado APRIL 1990 00974.wpf ALASKA ENERGY AUTHORITY BRADLEY LAKE HYDROELECTRIC PROJECT REPORT ON LOAD ACCEPTANCE ANALYSIS J.O.No.15800.52 Prepared by Stone &Webster Engineering Corporation April 1990 04/06/90 1.0 EXECUTIVE SUMMARY 1.1 Introduction 1.2 Alternatives and Modifications 1.3 Discussion of Results 1.3.1 Rapid Load Acceptance 1.3.2 Reduction of Combustion Turbine Load 1.3.3 Governor Operating Modes 1.4 Conclusions 1.5 Recommendation 2.0 SCOPE OF STUDY 2.1 Introduction 2.2 Objective 2.3 Approach 3.0 EXISTING DESIGN 3.1 General 3.2 Waterpassages 3.3 Turbines 3.4 Governors 3.4.1 Existing Governor Design 3.4.2 Possible Governor Modifications 4.0 SYSTEM STUDIES 4.1 Methodology of Hydraulic System Modifications 4.2 Hydraulic Transient Model 4.3 Power Ramping Curves 4.4 Acceptability of Hydraulic Transients 4.5 Power System Model 5.0 DISCUSSION OF ALTERNATIVES 5.1 General 5.2 Modification of Turbines 5.2.1 30 Second Needle Opening Time 5.2.2 Less Than 30 Second Needle Opening Times 5.2.3 Limitation of Needle Operating Time 5.3 Surge Tanks 5.3.1 General 5.3.2 Air Chamber 5.3.3 Surge Tank No.1 00974 .wpf .a | AB OF CONTENTS PWWNNYNHHE/nininuwowovontns11 ll ll 11 12 12 17 17 17 17 17 17 18 18 18 18 04/06/90 F_CONTENTS (Cont!d Surge Tank No.2 Surge Tank No.3 Comparison of Surge Tanks Nos.1 and 2 Summary Alternatives Comments Ramping Curves 6.0 DISCUSSION OF STUDY RESULTS PRPREWWUUNEeNeANAAAAARAAAAeo.eFWNHeComparison of Hydraulic Models Interconnected System Results Isolated System Loss of Anchorage-Kenai Intertie Kenai System Isolated Summary of Results Anchorage/Kenai Intertie Intact Loss of Anchorage/Kenai Intertie Kenai System Isolated Spinning Reserve Contribution 7.0 COST IMPACTS OF ALTERNATIVES General Surge Tank and Air Chamber _ Turbine and Governor Modification 8.0 CONCLUSIONS AND RECOMMENDATIONS 8.1 8.2 APPENDIX I APPENDIX II -USE OF COMBUSTION TURBINE PEAK RATING TO UTILIZE SPINNING RESERVE AT BRADLEY APPENDIX III -PLOTS FROM COMPUTER SIMULATION BY PTI 00974.wpf Conclusions Recommendations TRANSIENTS LAKE ii -METHODS FOR MITIGATION OF HYDRAULIC Page 19 19 19 21 21 21 22 23 23 23 25 25 26 26 26 27 27 28 30 30 30 30 31 32 31 I-1 II-1 TII-1 04/06/90 LIST OF TABLES TABLE 1 2 List of Hydraulic Cases Total Cost of Alternatives LIST_OF FIGURES FIGURE 1 2 Power Tunnel Profile Air Chamber Surge Tank No.1 Surge Tank No.2 Surge Tank No.3 Ramping Curve for Alternative I Ramping Curve for Alternative II Ramping Curve for Alternative III 00974.wpf iii.04/06/90 1.0 EXECUTIVE SUMMARY 1.1 Introduction The Alaska Railbelt Utilities are interested in maximizing the ability of the Bradley Lake units to provide spinning reserve for the Railbelt system.ThespinningreservepotentialofBradleyLakecanbecategorizedastwotypes;1)rapid load acceptance to respond to the initial generation need,and thusavoidfrequencydropand2)slower load acceptance to reduce load on combustion turbines that have provided the initial generation need.The relative amount of spinning reserve provided by Bradley Lake is related to the rate of loadacceptancebythehydroelectricunits.The load acceptance rate is dictated by the turbine needle opening times. This analysis,prepared by Stone &Webster Engineering Corporation (SWEC)andPowerTechnologies,Inc.(PTI,)evaluates the potential Bradley Lake spinning reserve capabilities by simulating three different turbine needle opening times. 1.2 Alternatives and Modifications Three alternatives,10,30 and 72 second effective turbine needle opening times, were selected for detailed study.The 72 second needle opening time corresponds to the existing design of the Bradley Lake Project.Shorter needle opening times require equipment modifications and result in transient pressure changes in the power conduit,possibly requiring the addition of surge tank(s). The three alternatives and the resultant transient operating conditions were incorporated into a system model by PTI.For each alternative,the system's frequency response was then examined based upon changes in generation requirements to evaluate Bradley Lake's spinning reserve contribution. The three alternatives analyzed in this report and corresponding designs are: ALTERNATIVE I -Existing Hydraulic,Turbine,and Governor Design: The effective needle opening and closing times are 72 seconds. No modifications to the existing water passage and equipment design are required. ALTERNATIVE II -Existing Hydraulic Design With Governor Control System Modification-30 Second Effective Turbine Needle Opening Time: The needle effective opening is adjusted to 30 seconds.The hydraulic needle control system and governor software require modification.There are no changes required to the water passages.The estimated direct cost increase is approximately $1.2 million. ALTERNATIVE III -Addition of Surge Tanks 10_Second Effective Needle Opening Time: The needle effective opening time is 10 seconds.Two surge tanks would need to be added.Extensive modifications are necessary to the hydraulic needle control piping and equipment, and electronic control systems.The estimated direct cost 00974.wpft 1 04/06/90 increase resulting from these modifications is approximately $15.2 million. 1.3.Discussion of Results The Bradley Lake units can provide spinning reserves at all three needle opening times studied.The amounts are summarized below. SPINNING RESERVE BENEFIT Combustion woceee Rapid Load Acceptance --------Turbine Peak Needle Interconnected System Kenai Isolated Rating Spinning Opening Time Lost gen -CT spin)Reserve Enabled 72 seconds 27 MW 3 MW 90 MW * 30 seconds 27 MW O MW 90 MW * 10 seconds 45 MW 10 MW 90 MW * *Based on minimum head with two units.At maximum head with two units,112 MW is available.: 1.3.1 Rapid Load Acceptance When the Kenai and Anchorage systems are interconnected,and when the Kenai is isolated with only hydroelectric generation on line,all three needle opening times provide some spinning reserve for rapid load acceptance.However,due to head drop associated with the fast needle movement,the 30 second time had a negligible spinning reserve benefit under isolated system operation.The rapid response spinning reserve capabilities of Bradley Lake are summarized as follows: Spinning Reserve Interconnected System Kenai Isolated Needle Opening Time Lost gen -CT spinning res (Largest feeder picked up) 72 seconds 27 MW 3 MW 30 seconds 27 MW O MW 10 seconds 45 MW 10 MW The above spinning reserve valves are the minimum available,provided that at least that much generation is available at Bradley Lake. 1.3.2 Reduction of Combustion Turbine Load All three needle opening times allow the load of the combustion turbines to be substantially reduced within the first minutes after a disturbance.The amount of this type of spinning reserve available is the same for all needle opening times studied,and equates to the full available rating of the Bradley Lakeunits.The only difference between the alternatives is the total lapsed time to achieve the full rated output.Load acceptance curves show that full output from the turbines can be achieved as shown below. 00974 .wpf 2 a i 94/11/90 Time To Full Load Needle Opening Time (From Speed-no-Load) 72 seconds 80 seconds 30 seconds 40 seconds 10 seconds 13 seconds* *Power output drops to 85%power by 70 seconds,recovering to 100%by 140 seconds. Since the units respond within 72 seconds for all three alternatives,operation of the combustion turbines up to their peak rating (assumed to be 10%over base rating)would be possible for all needle opening scenarios.Based on this,the addition of the Bradley Lake units can reduce the spinning reserve requirement from combustion turbines by as much as 100 MW (based on units at speed no load,and a 100 MW system spinning reserve requirement:Bradley lake 90 MW+10%peakrating).This spinning reserve contribution,however,may be limited by the power transfer capability of the Anchorage-Kenai intertie. 1.3.3 Governor Operating Mode Presently,the governor control is designed such that the needles operate in a sequential fashion to conserve water.However,in order to provide the most rapid response to load,all six needles of the turbines should open simultaneously.For purposes of this study,the model assumed that all needles open at the same time.An additional governor operating mode would have to be added to implement this function. 1.4 Conclusions The primary contribution of Bradley Lake as spinning reserve is derived by enabling the operation of combustion turbines at their peak rating for short durations to avoid frequency decay.Bradley Lake can accept load in less than 72 seconds up to its full capacity rating (nominally 90 MW)and back the _combustion turbines down below their base rating. The use of decreased needle opening times below the existing 72 second needle time,facilitated by surge tanks or other means,does little to avoid load shedding or to increase the spinning reserve capability of Bradley Lake.The small increase in spinning reserve value,and other minor improvements in frequency control,do not appear to justify the added expense for the required modifications. 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. 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 Bradley Lake or the Kenai is operating isolated.This governor modification can be made at little expense. 00974.wpf 3 04/06/90 1.5 Recommendations Based upon the results of the study,the following recommendations are made: 1.Maintain the current load acceptance rate (72 second needle opening time), and current hydraulic and equipment design. 2.Implement an additional governor operating mode providing for simultaneous operation of all six needles and allowing for deflectors to cut into the water stream. 3.Discontinue any further investigation of revised needle opening times or modified hydraulic system design including surge tanks. 00974..wpf .Bk,_4 oe 7 ___04/06/90 2.0 SCOPE OF STUDY 2.1 Introduction Due to the modest size of the Railbelt System,large generation losses result in significant frequency decay on the system.The consequence of not arrestingsuchfrequencydecaythroughrapidgenerationresponsewouldbealossofloadbyunderfrequencyloadshedding.For the existing system,without the BradleyLakeProject,the only method of avoiding a load shedding action would be toassurethatsufficientspinningreserveisavailableoncombustionturbineunits to compensate for large generation losses.This has inherent economic penaltiesinthatcombustionturbinesmustbeoperatedinapartiallyloadedstate. With the addition of the Bradley Lake hydroelectric units,additional spinning reserve is potentially available.While due to the slow response of most hydro-electric units spinning reserve to avoid load-shedding is normally provided by combustion turbines,hydroelectric generation is frequently used to reduce load on combustion turbines that provided power to avoid frequency drop and load shedding.To evaluate the capability and extent of Bradley Lake spinning reserve,it is necessary to determine the ability of Bradley Lake to respond to system disturbances to avoid underfrequency load shedding.The ability of the Bradley Lake units to provide spinning reserve is related to the load acceptance rate of the units. 2.2 Objective This study is an investigation of the potential for improving the Bradley Lake load acceptance rate and its ability to provide spinning reserve to the Railbelt system through the use of modified governor control and the application of surge tanks. 2.3 Approach At the request of the Alaska Energy Authority and the utilities participating in the Bradley Lake Project,Stone &Webster Engineering Corporation (SWEC)and Power Technologies,Inc.(PTI)began a joint investigation to examine the ability of Bradley Lake to provide spinning reserve in order to avoid interconected utility system load shedding and freqeuncy decay upon;1)loss of other system generation,and 2)islanding of the Kenai Peninsula.Modifications to the turbine,governor,and needle control system and the addition of surge tanks were considered.PTI performed system studies to determine if the proposed modifications to the present Bradley lake Project design could possibly avoid load shedding and frequency decay on the loss of generation or on islanding of the Kenai Peninsula. SWEC studied a number of proposed Bradley Lake Project modifications,including various surge tank types,their number,location,and configuration.Also,SWEC reviewed the present and possible governor operating modes with Fuji Electric Company,the turbine/generator manufacture,and Woodward Governor,the governor manufacturer.With the concurrence of AEA and the utilities,the alternatives considered for modeling and system studies are: 00974 .wpf 5 04/06/90 ALTERNATIVE I -Existing Hydraulic,Turbine,and Governor Design: The effective needle opening and closing times are 72 seconds. No modifications to the existing water passage and equipment design are required. ALTERNATIVE II -Existing Hydraulic Design With Governor Control Svstem Modification -30 Second Effective Turbine Needle Opening Time: The needle effective opening is adjusted to 30 seconds.The hydraulic control and governor software require modification. There are no changes required to the water passages.The estimated direct cost increase is approximately $1.2 million. ALTERNATIVE III -Addition of Surge Tanks 10 Second Effective Needle Opening Time; The needle effective opening time is 10 seconds.Two surge tanks would need to be added.Extensive modifications are necessary to the hydraulic turbine equipment and electronic control systems.The estimated direct cost increase resulting from these modifications is approximately $15.2 million. Other design alternatives were studied,but were dismissed as technically undesirable,more costly,or incapable of providing additional improvement in spinning reserve capability.These other design alternatives are discussed within this Report and its Appendices. Each alternative was studied to determine the extent of modification which would be required to the existing design.These modifications were evaluated and cost estimates prepared.Power ramping curves were developed for the Bradley Lake Project units to establish the amount of power generation available versus time. The spinning reserve capability was examined for each alternative for three conditions. 1)When Bradley Lake is operating on the interconnected system.The worst case generation loss is studied.It is considered to be loss of ML&P units #6 and #7 (111 MW). 2)When the system is operating connected and the Anchorage-Kenai intertie is lost.The Kenai is assumed to be importing 45 MW from Anchorage. 3)The Kenai is operating isolated from the rest of the system with only hydroelectric generation on line (Bradley Lake and Cooper Lake). Increasing levels of feeder pickup are used to determine the amount of load that can be picked up by Bradley Lake without load shedding. 45 MW as chosen as the practical limit of the existing transmission system. Since Bradley Lake could not support frequency or loss of this import,higher levels of import were not investigated. For each alternative and operating condition,the system frequency response was evaluated to determine the generation levels and spinning reserve capability ofBradleyLake. 00974 .wpf HB Sn an OA OE QQ)- 3.0 EXISTING DESIGN 3.1 General The present design for the Bradley Lake Hydroelectric Project is complete andthemajorityofthemajorconstructionandprocurementcontractshavebeenawarded.Work under these contracts is now in various stages of completion. As presently designed,the water passageway or power tunnel forms a continuous conduit without any surge tank or other means of transient pressure relief.This design was based on a study conducted at an early stage of the projectdevelopment,indicating that a surge tank would not be economically feasible. The major project components which relate to the hydraulic transients in the power conduit system are described below. 3.2 Waterpassages The water conveying conduit system between the reservoir and the hydraulic turbines is shown schematically on Figure 1.The water passages include:a power intake,an 11 foot diameter horizontal tunnel at El.1035.5';the high pressure gates;an 1l-foot diameter vertical shaft down to El.309';a 15,000-foot long 13-foot diameter tunnel;and a 2700 foot long 11-foot diameter steel lined tunnel portion,that manifolds to three penstocks. The water passages are designed to supply water to three turbines,at a total design flow of 2,223 cfs,with maximum reservoir at El.1190.6'.The total head loss under these operating conditions is 98 feet.The resulting water starting time is calculated at 8.7 seconds,and the travel time of a pressure wave round trip (2L/a)is 9.2 seconds,where "L"is the total length of the power conduit and "a"is the average velocity of pressure wave propagation. The design pressure at the turbine inlet is equivalent to 1470 feet of water pressure and the Hydraulic Grade Line (HGL)extends approximately linearly along the power tunnel length and meets reservoir elevation at the intake.The upper elbow on the vertical shaft is the highest point of the power tunnel with respect to HGL.A sufficient margin of above-atmospheric pressure must be maintained at this location to prevent water column separation.The crown of the upper elbow is at El.1041'. 3.3 Turbines Two Pelton type turbine-generator units,each capable of generating 63 MVA are being installed in the powerhouse.Provisions for a future additional third unit of a similar capacity have been made.Digital,fully programmable, governors are being supplied for each of the two units. The turbine needle valves are equipped with deflectors which,in case of a load rejection,can divert the full water jet streams away from the runner within 1.5 seconds and thus effectively offload the hydraulic power input.Closure of the turbine by means of the needle valves must be done in 72 seconds or more,as currently designed,otherwise the design pressure at the turbine inlet would be exceeded (3 units assumed). The total physical stroke of the turbine needle servomotors is 210 mm.A stroke of 169 mm is sufficient to generate guaranteed power output at all heads.The 00974 .wpf 7 04/06/90 turbine manufacturer provided spacers to physically limit the needle stroke to 178 mm.Since the replacement of the spacers is labor intensive (needle valves must be dismantled)the manufacturer provided a safety margin by limiting the needle stroke at 178 mm and not at 169 mm.The spacers actually occupy the parr of the stroke between 178 and 210 mm.To be able to use this part of the needle stroke for operation the spacers would have to be removed.The governor limits the stroke at the "full load position"which will be finally set after the field performance test.Presently the governor limit is set at 169mm.Therefore, under normal conditions the needle valves will operate between 0 and 169mm of stroke.In case of the governor malfunction the needles may assume any position between O and 178mm of stroke. In addition,the needle servomotors have a built-in "cushioning"feature which reduces both operating rates 2.78 times within the last 10mm of stroke near the "closed"position.As the normal practice in the industry,this feature is added to (1)prevent slamming of the servomotor piston against the stop while closing, and (2)mitigate head fluctuation after emergency closure of the needle valves. For the purposes of design calculations and governor adjustment,the closing and opening times are related to the total stroke of 210 mm.The present design is for a needle to travel within 90 seconds the 210 mm stroke in either direction. To avoid confusion,these operating times are referred to as "nominal". However,for the purposes of the load acceptance study it is more meaningful to use the "effective"needle operating times,defined as the time the needle needs to travel from the fully closed position to the position where full power output is generated (i.e.169 mm)and vice versa.Therefore,the 90-second nominal operating time equates to an actual 72 second effective operating time (exactly 72.43 sec).The velocity of the needle movement will be identical in both instances,i.e.2.33 mm/sec. The movement of the needles is controlled by the governor distributing valves located in the actuator cabinet.An electrical signal is linearly translated into displacement of the piston in the distributing valve.Displacement of the piston opens the valve port and allows pressure oil to flow into the needle servomotor.The displacement of the piston,i.e.opening of the port,controls the velocity of the needle movement.The piston has mechanical stops in each direction which allow adjustment of the maximum opening and closing rate independently.The design and the initial adjustment is for the nominal opening and closing needle time of 90 seconds (effective time of 72 seconds).When the third unit is added the setting of the distributing valves remains unchanged. The oil from the distributing valves is conveyed to the needle servomotors by 3/4"diameter stainless steel piping,partially exposed,partially embedded. There are two pipes for each needle servomotor:one with the pressure oil to open and one with the pressure oil to close.The pipes to all needle servomotors are arranged in a bundle between the turbine head cover and the actuator cabinet. In the case of failure of both pipes to one servomotor the needle would be subject to uncontrolled movement,possibly sudden closure.That would cause an intolerable water hammer.For this reason SWEC required the addition of an antislamming orifice which would restrict movement of the needle to a 60 second nominal rate,for the two unit installation,even if the servomotor piping is lest.To comply with this requirement,the turbine manufacturer installed a fixed orifice into the "close"pressure oil conduit inside the needle valve bodywhichrestrictsboth,the opening and closing rates to the 60 second value.A 00974 .wpE Bn 04/09/90 . 60-second nominal closing time for a two-unit operation produces a transient overpressure in the turbine inlet which is within the design pressure of 1470 ft.When the third unit is added,the orifices in the needle servomotors must be replaced with smaller orifices which restrict the nominal operating times to 90 seconds.The 90-second nominal closing needle time is required to maintain the maximum transient overpressure causedby load rejection of three units within the design pressure of 1470 ft. 3.4 Governors The governors for the Bradley Lake units are Woodward Governor Co.Model 501 digital governors.As such,the governing algorithm is programmed in software. This gives great flexibility in governor control algorithm design and modifications.Presently,the governor is designed with two operating modes, 1)Grid and 2)Isolated.Each utilizes different control functions and Proportional,Integral,and Derivative (PID)gains. 3.4.1 Existing Governor Design The Grid mode operates as a turbine power regulator.It controls unit power output based on a power setpoint provided by the operator.This mode is used when the unit is connected to a grid where other units provide system frequency control.This mode while regulating power,also utilizes speed feedback to ensure that the unit does not contribute to system speed deviations.Because of this feedback,the units react to speed errors even though the "control" parameter is power. In the Isolated mode the governor operates as a droop governor similar to conventional analog and mechanical governors.It controls the unit speed based on a speed setpoint provided by the operator.The unit is loaded by raising the speed setpoint above system frequency according to the droop curve.The Isolated mode is used prior to closing of the generator breaker,and when the unit is supplying power to a weak or isolated system. During both modes of operation,the governor controls the number of needles in operation to obtain the best efficiency for the required load.The needles sequence from shutdown to 2,3,4 and 6 needles in operation.The number of needles in service is determined by the actual unit power output when operatingintheIsolatedmode,and by the power setpoint when operating in Grid mode. Thus when the system frequency drops,the unit in Grid mode will only open thoseneedlesalreadyoperating.Since the unit power output increases as speed dropsforaconstantmechanicalinputpower,in Isolated mode the number of needles opening will increase as the output power increases. 3.4.2 Possible Governor Modifications The sequencing of needles,as described above,while utilizing the available water most efficiently,will at low initial power settings,lengthen the time required for the units to achieve full power output.Thus depending upon theinitialloadsetting,the unit's response to under-frequency conditions may berestrictedbythegovernorcontrolalgorithn. Since this study examines methods to improve the load acceptance of the BradleyLakeunits,and assuming that maximum load acceptance is more important thanefficiency(for the purposes of this study),this study operates all six needlessimultaneouslyatthespecifiedgovernorrate(i.e:10,30,and 72 second 00974.wpt 9 04/06/90 effective needle operating times).To implement this in the Bradley Lake, governors would require an additional (third)operating mode. An additional mode of operation can easily be added to the existing governor by modifying the software.This mode could be triggered from SCADA on an islanding signal,under freqency,or the dispatcher or operator could switch to this mode when freqency regulation is required from Bradley Lake. To obtain the fastest Bradley Lake response in order to provide significant frequency regulation,it would be necessary to operate the turbines with the deflectors partially engaged.While this operating mode was not studied,since power would be controlled by the "fast"deflectors (1.5 seconds full stroke) rather than the "slow"needle valves (10,30,or 72 seconds full stroke)this would provide the fastest frequency control.To facilitate this type of control, the above third operating mode would be modified so that all six needles are opened wider than required by the load and the deflectors engaged to control speed as a zero droop governor.An "enable/disable"switch could be provided to permit the operator to lockout this mode depending on system configuration. Due to the ineffeciencies of this mode of operation,it should only be used for short periods of time. While this third mode would waste energy and cause additional wear on the turbine and deflectors,it would permit the fastest loading of the Bradley Lake units. Since the deflectors do all of the flow modulation,this mode of operation would require no modification of the water passages. 00974.wpf See on 10 oe :04/06/90 4.0 SYSTEM STUDIES 4.1 Methodology of Hydraulic System Modifications The concept for each Alternative (outlined in Section 2.2)was developed using the following steps: 1.The modification of the existing design (such as surge tank dimensions,etc.)was based on experience,simple empirical formulas and charts. 2.The arrangement,as per Step 1 above,was modeled by a computer assisted hydraulic transient model to obtain the hydraulic characteristics in the system.List of modeled cases is shown on Table 1. 3.Data obtained in Step 2 were evaluated and the arrangement either adopted for the given alternative or further modified and Steps 1 through 3 repeated.Three alternatives were selected to give 72,30, and 10 second effective needle opening times. 4.The dimensional,hydraulic,and performance data of the selected alternatives were used as the input for mathematical modeling of the power system performed by PTI. 5.Direct construction and/or equipment modification costs were estimated for each selected alternative. 6.Power ramping curves,showing turbine-generator unit power output versus time during a load acceptance,were developed. 4.2 Hydraulic Transient Model Transient conditions following load acceptance and load rejection in the waterpassages were simulated by means of Stone &Webster's computer program HY-1,Hydraulic Transient Analysis Program.The program applies the method of characteristics and elastic wave theory to obtain the solution of the transient in the waterpassages.The computer program simulated the transient interaction of the power tunnel,penstock manifold,penstocks,turbines,and up to two surge tanks.The program calculates the static head,water level,and flow at selected locations and at predetermined time increments.The output data were used to plot ramping curves and to verify dimensions of the surge tanks,specifically the lower and upper elevation of the surge tank bowls. 4.3.Power Ramping Curves The output data from the hydraulic transient program,plus turbine efficiency and generator efficiency were used to calculate generator power output and to develop power ramping curves,which consist of the generator output during load acceptance versus time.Plots of the ramping curves are shown on Figures 6,7, and 8, Generator and turbine efficiencies as per the current contract with Fuji Electric for supply of the turbines and generators were used.The turbine efficiency which is based on the model test data,covers the operating conditions for needle stroke higher than 34.4 mm and heads above 800 feet.Efficiencies for needle 00974.wpft ll 04/06/90 openings smaller than 34.4 mm and for net heads lower than 800 feet were estimated. 4.4 Acceptability of Hydraulic Transients The computer output data were checked against acceptance and operationalcriteria.Adjustments were made to the surge tank system alternatives and otheroperatingparametersinordertoremainwithintheseacceptancecriteria.Oneoftheacceptabilitycriterialimitingtheloadacceptancerateconsiderationsistheabsolutepressureattheelbow(STA 184+76)on the top of the vertical shaft.The present minimum pressure (HGL =1052')which is 11 feet above the crown of the elbow,was used as the limiting factor.Operating alternatives resulting in less pressure than this minimum were rejected. Acceptability criteria for the load rejection cases is not to exceed the design pressure of 1470 feet at the turbine inlet. 4.5 Power System Model This analysis considered the Railbelt System operating under 1988/89 Winter Peak load conditions.PTI's PSSE program was used to model the system.Two overall conditions were studied;(1)Connected with the Railbelt system,and (2)Kenai islanded.Frequency dependent load characteristics were incorporated in the system representation. Underfrequency load shedding was not represented in the simulations.For most situations considered,system frequency was not expected to dip into the underfrequency load shedding range.Moreover,it was deemed important to avoid masking with underfrequency load shedding the natural ability of generation to correct for system frequency decay.Inspection of system frequency plots reveals whether underfrequency load shedding would come into play for the situations modeled.Data and models for the existing Kenai generation developed from the recent machine tests were incorporated in the system model.The Bradley Lake units were modeled using data obtained at the tests of the Bradley Lake governors at Woodward Governor,and using standard models.Typical models were used for the other generators in the railbelt. For all combustion turbines in the Railbelt System,the models were modified in order to allow the combustion turbines,in response to below-normal frequency conditions,to reach sustained output levels equal to their peak ratings.The Railbelt utilities have indicated that they may be willing to allow their combustion turbines to operate at 10%over the base rating for several minutes. Bradley Lake must accept sufficient load to back the combustion turbines down to their base rating in this time period.This capability "extends"the amount of spinning reserve available from a combustion turbine.For each combustion turbine,the peak rating was considered to be 10%greater than the base rating. A discussion of combustion turbine operating capabilities and a method of implementing such a scheme is included in Appendix II to this report.Inclusion of this capability did not alter the initial operating state of any combustion turbine in the simulations.All combustion turbines were modeled as having initial output levels equal to or below the winter base ratings.Further, inclusion of this capability did not alter the transient response of the combustion turbines to below-normal frequency excursions.The transient response (i.e.,the first two to three seconds following a disturbance)of a combustion turbine is limited only by the response characteristics of the governor and the fuel system regardless of the sustained output limit (base or peak)under which 00974 .wpft 12 __....04706790 the turbine is allowed to operate.A combustion turbine can go to full fuel flow output levels for two to three seconds before the slow acting exhaust temperaturelimitingcontrolsreturntheturbineoutputtotheallowable(base or peak) sustained rating. For the cases without as well as with Bradley Lake,the combustion turbines were allowed to go to this peak rating.This was done to facilitate comparison toseetheeffectoftheBradleyLakeUnits.This is not how the Railbelt utilities presently operate their turbines,and may not be a desirable operating mode duetotheageofsomeoftheunits,and the system reliance on the combustion turbines for the bulk of the power generation. The contingency evaluated for all cases with the system intact,was thesimultaneouslossoftheAMLPUnits#6 and #7 combined cycle pair.This combined cycle pair can trip simultaneously due to the relaying configuration used,and represents the worst,probable instantaneous generation loss the Railbelt System could encounter.Further,the output of this combined cycle pair had the same initial conditions in each simulation and provided a disturbance of equal magnitude for all situations evaluated. For this analysis,all simulations representing the effects of Bradley considered both Bradley units to be on-line.It was also assumed that the governors associated with the Bradley Lake units operated in a frequency regulation mode (isolated mode).All six needle valves on each of the Bradley Lake units were assumed active for all Bradley Lake output levels.The Bradley Lake governors were modeled with an extremely small droop characteristic (0.1%).This maximized the response capability of the Bradley units to system frequency excursions,and it assured that the Bradley units would reach full output by attempting to cause system frequency to recovery to near 60 Hz.Thus,the load acceptance of the Bradley units,as modeled,is limited only by the rate at which the needle valves moved plus any constraints imposed by the hydraulic design.Performance capabilities similar to those modeled could be achieved through modifications to the Bradley Lake governors and by the implementation of the proper control strategies as part of the present Automatic Generation Control (AGC)system. The simulations performed are shown on the case list below.A listing of initial-condition generation levels and plots of frequency and Bradley Lake response are included in Appendix III of this report.The study sequence was to first evaluate system response without Bradley Lake (the present day situation),Case 1.Then,Bradley was modeled on-line with the three different hydraulic configurations simulated,Cases 2 through 6.In successive cases, simulations were performed where the amount of spinning reserve available from combustion turbines was gradually reduced.This reduction was accomplished by removing partially loaded combustion turbines one at a time,thus reducing both the system inertia and the amount of available combustion turbine spinning reserve.Reduction of combustion turbine spinning reserve was continued until the present Bradley design (mo surge tank and 72 second effective needle operating times)failed to keep the system frequency above the levels at which load shedding would occur,Case 6. The system was then modeled with only Bradley Lake and the Tesoro unit on line on the Kenai,with a 45 MW Kenai import for the three hydraulic configurationsandtheintertieopened,Case7.As a comparison,the same was done with onlycombustionturbinesoperatingontheKenai,Case 8.The Tesoro unit was modeled without a governor and thus had no influence on system frequency. 00974 .wpt 13 04/06/90 Case 9 is when the Kenai is isolated with only Bradely Lake and Cooper Lake on line.Various levels of feeder pickup are studied. CONTINGENCY: CASE #1: FILE: WP88NBOL CASE #2: FILE: WP88BO01 WP88D01 WP88FOl CASE #3: FILE: WP88COL WP88E01 WP88G0O1 CASE #4: 00974.wpf --- LOAD ACCEPTANCE ANALYSIS SUMMARY PTI COMPUTER RUNS (All cases)System intact with simultaneous loss of AMLP Units #6 and #7 carrying 111 MW. 1988/89 Winter Peak.Bradley off-line.All spin carried on CTs.168.6 MW of peak rate CT spin. DESCRIPTION: Spinning reserve response from CTs only. 1988/89 Winter Peak.Bradley on-line at 40 MW.Steam and hydro generation reduced.168.6 MW of peak rate CT spin and 80 MW of spin on Bradely. DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.Bradley on-line at 40 MW.Bernice Lake Units #3 &#4 off-line and steam generation reduced.135.6 MW of peak rate CT spin and 80 MW of spin on Bradley. DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.Bradley on-line at 46 MW.Bernice Lake Units #3 &#4 and Soldotna off-line.97.6 MW of peak rate CT spin and 74 MW of spin on Bradley. Oe 04/06/90 FILE: WP88CO2 WP88E02 WP88G02 CASE #5: FILE: WP88C03 WP88E03 WP88G03 CASE #6: FILE: WP88C04 WP88E04 WP88G04 CASE #7: FILE: WP88QO01X WP88RO1X WP88S0O1X CASE #8: 00974.wpf DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.Bradley on-line at 51 MW.Bernice Lake Units #3 &#4,Soldotna and AMLP Unit #1 off-line.83.9 MW of peak rate CT spin and 69 MW of spin on Bradley. DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.Bradley on-line at 51 MW.Bernice Lake Units #3 &#4,Soldotna,AMLP Unit #1 and North Pole #1 off- line.Load reduced in Fairbanks.65.9 MW of peak rate CT spin and 69 MW of spin on Bradley. DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.All Kenai generationoff except BradleyLake,43 MW,and Tesoro,4 MW.45 MW transfer at University into Kenai.Isolate Kenai by loss of intertie. DESCRIPTION: Existing Bradley hydraulics W/90 second needle stroke rate. Existing Bradley hydraulics W/30 second needle stroke rate. Bradley W/10 second needle stroke rate &surge tank. 1988/89 Winter Peak.Cooper Lake,Bernice Lake Units #3 & #4,and Soldotna supplying Kenai load.Isolate Kenai by lossofintertie. 15 04/06/90 FILE:DESCRIPTION: WP88LO01X Bradley off-line. CASE #9:1988/89 Winter Peak.Kenai isolated.Bernice Lake,Soldotna off.Cooper Lake held at 16 MW.Bradley Lake at 72.5 MW. FILE:DESCRIPTION: Existing Bradley hydraulics W/90 second needle time with: SH SH SH WP88TO1X Pickup of 3 MW feeder. WP88U05X Pickup of 5 MW feeder. WP88U01X Pickup of 7 MW feeder.FwhnExisting Bradley hydraulics W/30 second needle time with: SH 5 WP88T0O2X Pickup of 3 MW feeder. SH 6 WP88U02X Pickup of 7 MW feeder. Bradley W/10 second needle time and surge tank with: SH 7 WP88TO3X Pickup of 3 MW feeder. SH 8 WP88U03X Pickup of 7 MW feeder. SH 9 WP88U04X Pickup of 10 MW feeder. 00974 .wpt -----8 6 -0470690 - 5.0 DISCUSSION OF ALTERNATIVES 5.1 General This section discusses the individual design elements used to modify the existing waterpassages and turbine/governor equipment,their effects,and limitations relevant to the needle opening time reduction. 5.2 Modification of Turbines 5.2.1 30 Second Needle Opening Time Some modifications of the existing turbines and governors would be necessary to allow a needle opening time of 30 seconds without changing the closing rate restriction.It would include providing separate anti-slamming orifices for close and open oil conduits in the needle valve body.Check valves would have to be added so that flow in opposite directions can bypass the orifices.The needle servomotors,needle servomotor oil piping,and governor hydraulic system as designed are capable of supporting the needle operating time of 30 seconds. Orifices capable of limiting the closing and opening rates separately would have to be built into the needle valve flange.If.no surge tanks are added,the nominal closing needle time must remain at 90 seconds in order to comply with the design pressure limits of the turbine equipment and waterpassages. 5.2.2 Less than 30 Second Needle Opening Times Major modifications of the turbines and governors would be necessary to achieve effective needle opening times shorter than 30 seconds.The shorter the closing time required,the more extensive the modifications would need to be.The following changes to the equipment would be envisioned: COMPONENT CHANGE REQUIRED needle valves modify/replace head cover &pit liner modify governor needle piping replace governor distributing valves replace accumulator tank possibly replace oil sump tank replace governor electronics modify For opening times in the order of 10 seconds or less,the operating control oil pressure might have to be increased.In such a case a new accumulator tank would be required.This would further require either redesign of the spherical valve control system for increased oil pressure or an alternative source of oil pressure for the spherical valve. 3.2.3 Limitation of Needle Operating Time Several leading manufacturers of Pelton turbines,Escher Wyss of Switzerland, Kvaerner Brug of Norway,Vevey of Switzerland,and Neyerpic of France,were questioned as to the minimum needle operating time for Pelton turbines. Essentially identical responses were received from all four manufacturers,stating that it would not be technically difficult to design needle valves of a Pelton turbine with operating times on the order of 4-5 seconds.It would be 00974.wpf 17 04/06/90 only a question of properly sizing the piping,ports,and flow sections for the control oil system in general. However,such short needle operating times have never been required for a Pelton turbine.The shortest needle opening time which any of the four manufacturers ever provided for a Pelton turbine of Bradley Lake size is 10 seconds.Thus,SWEC would not recommend needle operating times shorter than 10 seconds without extensive investigation of the entire system. 5.3 Surge Tanks §.3.1 General Figure 1,Power Tunnel Profile,shows the alternative locations of three different surge tanks and one air chamber considered under this study. §.3.2 Air Chamber An air chamber was considered in the event that it became desirable to achieve an extremely short needle opening time.The conceptual configuration for the air chamber is shown on Figure 2.To accommodate short needle opening times, (on the order of 4-5 seconds)this surge device would have to be located as close to the powerhouse as possible (STA 6+40). Shallow rock cover dictated selection of a steel air chamber in lieu of a surge tank.This alternative was not pursued any further since the minimum needle opening time was established at 10 seconds and that could be accommodated much more economically by the surge tanks as discussed later. 5.3.3 Surge Tank No.1 Surge Tank No.1 (Figure 3)would be located at STA 36+63 where the ground topography is at El.1100',thus providing the closest practical location to the powerhouse for a surge tank.Even at this topographic location,the surge tank would have to be extended above ground,since the water level during normal operation and during upsurge exceeds the ground level.An above ground concrete structure,consisting of a circular tank with segregated concrete wall thickness would be used to form an extension of the surge tank.Six radial butresses would support the tank laterally during an earthquake. The riser diameter was selected at 13 feet.No orifice or flow restriction devices would be used in order to maximize the pressure wave traveling into the surge tank and minimize the pressure wave traveling towards the intake.This would be done in order to meet the criteria for maintaining the highest pressure possible at the upper elbow during a load acceptance,and prevent occurrence of sub-atmospheric pressure,leading to a possible water column separation at this location. This surge tank was originally selected to facilitate a 10 second needle opening time.As can be seen from Table 1 (Cases DO3 and DO8)this was not achieved. Pressures at the upper elbow would be too low.Two additional modifications to this arrangement were investigated in an attempt to increase the pressure at the upper elbow after a 10 second load acceptance:(1)Increase of the diameter of the tank bowl (50 ft was simulated)proved to be ineffective.(2)Increase of the diameter of the riser (20 ft was simulated)would raise the minimum pressure in the upper elbow to El.1051'for a two-unit operation which would have a 00974.wpf SB 04706790 sufficient margin to prevent occurrence of sub-atmospheric pressure at thislocation.The minimum pressure in the elbow for a three unit operation would be at El.1037'which was deemed unacceptable. This surge tank could be used for a 20-second needle opening time for a two-unit operation.Should a third unit be added,the needle opening time for thethirdunitwouldhavetobesomewhatlongerthan20-seconds (on the order of 60 seconds)so that the pressure at the upper elbow would be increased above El 1045'as calculated by Case DO2.(See Table 1). 5.3.4 Surge Tank No.2 Surge Tank No.2 (Figure 4)would be located at STA 60+78 where ground elevation reaches El.1300'.At this location,the top of the tank would need to be extended 30 feet above the ground in order to contain surging water.With a diameter of 25 feet the portion of the tank above the ground would have an aspect ratio of about 1.0 and would not need any additional lateral support.The riser diameter would be 13 feet and no orifices and restrictions would be used for the Same reasons as given the case of the Surge Tank No.l. Similarly as No.1,this surge tank (No.2)(1)-.can not be used for a 10 second needle opening time (neither for a 3-unit nor for a 2-unit operation)since the pressures in the upper elbow would be two low and the danger of the water column separation eminent.See Table 1,Cases D13 and D15.(2)it could be used for a two-unit operation.Again,should the third unit be added,the opening needle _time for the third unit would have to be longer than 20 seconds,say 60 seconds. 5.3.5 Surge Tank No.3 Surge Tank No.3 (Figure 5)would be located at STA 184+14 and represent an extension of the 11-foot vertical power tunnel shaft above ground surface,to El.1290°. This surge tank if used alone,would not improve the low pressure situation in the upper elbow significantly.However,Surge Tank No.3 would be quite effective if used in combination with either Surge Tank No.1 or No.2.See Cases D51 and D52 on Table 1.For both,2-unit and 3-unit operations,the minimum pressure in the upper elbow would be sufficiently high so that the water column separation would not occur. 5.3.6 Comparison of Surge Tanks Nos.1 and 2 Either Surge Tank No.1 or Surge Tank No.2 when used alone could facilitate a 20-second needle opening time for a two-unit load acceptance.However,there is a slight difference in the two corresponding power ramping curves.The ramping curve for Surge Tank No.1 shows a reduction of power to 52 MW within 130 seconds (quarter-cycle)due to the downsurge in the surge tank subsequent to a full load acceptance of two units.Similarly,the ramping curve for Surge Tank No.2 shows reduction of power to 49 MW (after 75 seconds). By increasing No.2 Surge Tank diameter it would be possible to make the downsurge and power dip comparable to that of Surge Tank No.1.Cycle time of the surge can not be changed since that is an inherent feature of the location of the surge tanks.The upward and downward movement of the water level in a surge tank is periodical.The function of the movement versus time is 00974.wpft 19 04/06/90 sinusoidal.A cycle time is defined as a period between two subsequent upsurges (peaks). In view of these facts,and in consideration that neither surge tank can facilitate a 10 second needle opening time within the prescribed operational and safety criteria,and,further,taking into account the higher cost of Surge Tank No.1 this surge tank configuration was not considered in further assessment studies presented by this report.As discussed later a 10 second alternative could be achieved by combination of Surge Tanks Nos.2 and 3. 00974 .wpft -ee 200°.woo 04706790 5.4 SUMMARY 5.4.1 Alternatives The following modifications of the waterpassages and equipment would be required to satisfy the three Alternatives defined in Section 2.2 for two-unit operation: ALTERNATIVE I -Existing Hvdraulic,Turbine,and Governor Design: This is the current design of Bradley Lake Project,as described in Chapter 4.0,with an effective opening needle time of 72 seconds for the turbine units.No modifications to the existing water passage and equipment design are required. ALTERNATIVE II -Existing Hydraulic Design with Governor Control Svstem Modification -30 second effective Turbine Needle Opening Time: A 30 second effective needle opening time could be achieved without the need for surge tanks and only with minor modifications to the turbine and governor equipment as described in Paragraph 5.2.1..If the third unit is added the needle closing times of all three units will have to be extended (to approximately 45-50 seconds)to meet the pressure criteria in the upper tunnel bend.It may be possible to use different effective needle opening times for the three-unit operation (say Unit 1 at 30,Unit 2 and 3 at 72 sec)so that at least one unit can stay at 30 seconds. ALTERNATIVE III -Addition of Two Surge Tanks Modification -10 Second Effective Needle Opening Time A 10 second effective needle opening time could be achieved provided Surge Tank No.2 and Surge Tank No.3 are added to the existing waterpassages.Further extensive modification of the turbines and governors,as described in Paragraph 5.2.2, would be required.This alternative is based on Case D52 listed in Table 1. The PTI computer model can simulate only a waterpassage system with one surge tank.Therefore,Case D52 could not be used in the PTI analysis.For the PTI analysis,Case DO1 was used for the 10 second cases.Case DO1 uses Surge Tank No.1 with a 20-foot riser.This case is a technically feasible case,fully applicable for a 10 second needle opening time with two units operating. 5.4.2 Comments The deflector opening time of 1.5 seconds can be maintained for all Alternatives allowing the load to be rejected at this rate. The effective needle closing times for Alternatives I and II will remain unchanged at 72 seconds.For Alternative III,the needle closing time could bereducedaslongasthefullloadrejectionforthreeunitsdoesnotcausethe design pressure at the turbine inlet to be exceeded.However,since the deflector is provided,the only benefit of a shorter needle closing rate isslightlydecreasedwaterwaste. 00974 .wpf 21 : 04/06/90 39.4.3 Ramping Curves Ramping curves of power output versus time (Figures 6,7 and 8)were developed for selected alternative needle opening times,as indicated in Table 1.The ramping curves are included in this report for information.They are not needed as an input for the mathematical model used by PTI. The curves show that full power is reached in a time period longer (depending on the hydraulic configuration)than the effective needle opening time.This is caused by the transient head drop in the water flow system due to rapid acceleration of the water column.In cases with a surge tank,the power output starts to decrease after reaching its highest value at the end of the opening stroke.This is due to the downsurge in the surge tank which results in reduction of turbine head and the consequent reduction of turbine flow. Reduction of power due to a lower turbine head and flow is amplified by the decrease in turbine efficiency which also results from the reduction of turbine head and flow. -00974.wpf .Be ee 22 0406/90 6.0 DISCUSSION OF STUDY RESULTS 6.1 Comparison of Hydraulic Models The hydraulic transient model used by SWEC and the hydraulic part of the PTIsystemmathematicalmodeluseadifferentapproachfordeterminationoftransientheadandflow.SWEC's model makes stepwise calculations and performs integrations of direct and reflected pressure waves at key locations.PTI'smodelisalumpedparametermodelwhichusesanempiricalalgorithmtocalculate turbine head versus time.The PTI model does not account for the effects of travelling and reflected waves. The two programs give slightly different results.The turbine heads for the 30 and 72 second alternatives were compared.The turbine heads calculated by PTI 2 seconds after the disturbance were 7 (30 second)and 3 (72 second)percent lower,and 9.5 seconds after the disturbance were 11 (30 second)and 6.5 (72 second)percent higher than heads calculated by SWEC's model.These differences will affect the power output,and thus the frequency change.This report uses the PTI model as part of their PSSE program to analyze frequency response.The SWEC model is used for the hydraulic analysis for the surge tank design. The effect on the frequency response,is that the initial frequency drop in all cases may not be as low as shown on the plots,and the frequency recovery after the initial drop may not occur as rapidly as shown.The difference estimated is on the order of .05 Hz (.08%)low at 2 seconds after the disturbance,and 0.1 Hz (0.17%)9.5 seconds after the disturbance.This is well within the 2%error assumed for all calculations,plots,ete.in this study.Hence,all frequency numbers are stated as shown on the plots. PTI will modify their governor model to use a traveling wave model,and the exact governor structure for Bradley Lake for the TASK 3 system stability studies. 6.2 Interconnected System Results For the situations considered in this analysis and the interconnected systen, Cases 2 through 6,the simulations demonstrate that the Bradley Lake units, regardless of the hydraulic design,will have minimal affect on system frequency within the first one and one-half to two seconds following a large generation loss.For all cases,there is no apparent frequency difference one second after the generation loss for each of the three needle opening rates.From one second to two seconds after the loss of generation,there appears a difference in frequency between the ten second needle opening and the 30 and 72 second of approximately 0.05Hz.This amount does not appear to significantly rely on the amount of combustion turbine spinning reserve available.See sheet 2 of cases 2 through 6. The amount of combustion turbine spinning reserve has the dominant influence on system frequency and its initial rate of decay within the first two seconds. System frequencies vary from 59.6 Hz for a combustion turbine spinning reserve of 168.6 MW (Case 2)to 59.35 Hz for a combustion turbine spinning reserve of 65.9 MW (Case 6). Within the period of two to three and one-half seconds following a large generation loss (the period when the first step of load shedding would typicallyoccur),Bradley Lake will have a very minor detrimental effect on system 00974.wpf 23 04/06/90 frequency if the existing hydraulic design is coupled with a 30 second effectiveneedleopeningtimeascomparedtothe72secondneedletime.Bradley will haveasmallpositiveeffectonsystemfrequencywhenthesurgetanksand10secondeffectiveneedleopeningtimeareutilized.However,for this time frame, regardless of Bradley's hydraulic configuration,the system frequency wouldremainabovethefirstloadsheddingpoint(59.3 Hz)if the amount of peak rate spinning reserve available from combustion turbines is approximately equal toorgreaterthanthegenerationloss.See cases 2 through 6. For the time period three and one-half seconds or more following a large generation loss,the surge tanks and 10 second effective needle opening time on Bradley accelerates the rate of system frequency recovery,as compared to the 72 second needle time.Bradley Lake's contribution toward avoiding multiple steps of load shedding was crucial only when the amount of combustion turbine peak rate spinning reserve was significantly less (e.g.,45 MW)than the generation loss,Case 6.In this case,the 10 second needle time avoided load shedding while the 72 and 30 second needle time continued to decay below multiple load shedding points.Also for this time period,when the amount of peak rate spinning reserve available from combustion turbines is approximately equal to or greater than the generation loss,all hydraulic configurations for Bradley will arrest system frequency decay sufficiently.enough to avoid multiple steps of load shedding (Case 2-5).However,the existing hydraulic design with 30 and 72 second needle opening times will come very close to the first load shedding step. After ten seconds there is significant difference in frequency between the ten second needle opening time and the longer times.This difference is greater the lower the amount of combustion turbine spinning reserve available.With a combustion turbine spinning reserve of 168.6MW (Case 2)the difference is approximately 0.4 Hz,and with a combustion turbine spinning reserve of 65.9 MW (Case 6)it is approximately 1.2 Hz.The difference between the 30 and 72 second effective needle opening times not larger than .1 Hz,for a combustion turbine spinning reserve of 65.9 MW. For the situations modeled,a phenomena worth noting was observed.This phenomena was the development of growing voltage oscillations at Soldotna as the Kenai export approached the steady-state stability limits.This phenomena was most pronounced for the situation where the Bradley Lake hydraulic design utilized the surge tank and rapid needle valve stroke rate,and the spinning reserve available from Bradley was achieved in less than 10 seconds.The rapid rate of export change from the Kenai aggravated the onset of this voltage oscillation condition. This phenomena would not have occurred if the recommended automatic capacitor switching at Soldotna had been modeled in the simulations.However,the occurrence of this phenomena does underscore the fact that the amount of spinning reserve available from Bradley Lake may be limited by the Kenai export limits and not by the actual amount of spinning reserve the Bradley units can produce. Moreover,it points to the fact that the secure utilization of Bradley's spinning reserve capability is highly dependent on all automatic schemes functioning properly.This would be particularly true if the very rapid response characteristics were incorporated into Bradley's design.Under such a situation, there would be inadequate time for operator intervention (such as manual capacitor switching or the limiting of Bradley's output)to avoid stabilityproblemsintheKenaiduetomalfunctioningautomaticcontrolschemes.For Bradley”s presently designed 72 second needle valve stroke rate,operators may 00974..wpE ;_24 04/06/90 _ have adequate time to intervene if power increases from Bradley began to encroach on the secure operating capability of the Kenai area. Assuming a required system spinning reserve of 111 MW (ML&P Unit 6 and 7),Bradley Lake provides at least 27.1 MW (111 MW -83.9 MW peak combustion turbinespinrequired)with a 72 second needle time,see Case 5,and 45 MW with a 10secondneedletime.In addition,Bradley Lake can provide up to its rating of spinning reserve to reduce load on combustion turbines operated to their peak rating.In Case 5,this is 61 MW,112 MW rating -51 MW initial operating point. Thus,Bradley Lake can provide at least 27 MW of spinning reserve,and allow at least 61 MW of combustion turbine base rate spinning reserve to be replaced with peak rate spinning reserve (in case 5). 6.3 Isolated System 6.3.1 Loss of Anchorage-Kenai Interite For the Kenai islanding portion of this analysis,both units at Bradley LakeweremodeledasbeingtheonlyKenaiareagenerationon-line!.The Kenai was modeled as importing 45 MW as measured at the University 115 kV bus.The response of the system was measured followingthe opening of the Anchorage- Kenai tie at University. Simulations of this condition,Case 8,demonstrated that the Bradley Lake units, regardless of the hydraulic design,will not provide the power necessary to offset the loss of the tie and arrest frequency decay at levels above which underfrequency load shedding will occur.With the 72 second effective needle opening time the frequency at the Bradley Lake bus drops below 50Hz.The 30 second effective needle opening time shows some improvement but still drops to approximately 50.2Hz.Even when surge tanks and 10 second needle opening times are considered,the Kenai frequency dips to approximately 54.5 Hz before it recovers.This frequency level is well below the lowest underfrequency load shed point being considered for the Kenai area. For all three alternative needle opening times,the frequency does recover to near normal even without modeling the effect of underfrequency load shedding. The 72 second needle opening time restores frequency in excess of 30 seconds, the 30 second in 20 seconds,and the 10 second restores frequency in approximately eight seconds.From this perspective,there is an advantage to the 10 second in restoring system frequency after isolation from Anchorage. However,the effect of under frequency load shedding will shorten all times to the restoration of frequency.In addition,depending on the settings of underfrequency relays at Bradley Lake,in all cases the Bradley Lake units may be tripped off line within the first underfrequency period (three to five seconds). As as comparison,a case was run without Bradley Lake on line,Case 8,the present condition.Under the same Kenai import level (i.e.,45 MW),islanding of the Kenai with the Bernice Lake #3 and Soldotna combustion turbines on-line (also Cooper Lake at its full output level)results in the Kenai frequency dropping to nearly 58 Hz and recovering to about 58.5 Hz.Although this situation will lead to underfrequency load shedding,the frequency drop under IThe Tesoro unit was also on-line,was not represented with a governor andthereforehadnoeffectonthefrequencyinthedynamicsimulations. 00974.wpf 25 04/06/90 this condition is only one-third of that which results when Bradley with a 10 second effective needle opening time is employed.These simulations demonstrate the rapid response capability of combustion turbines and demonstrate that even with surge tanks,a hydro unit such as Bradley can not be made to perform at the same level.Thus in order to avoid load shedding on the Kenai when the pennunsula is islanded,has been separated from the Railbelt systen, combustion turbine spinning reserve must be provided on the Kenai pennunsula. 6.3.2 Kenai System Isolated For the Kenai isolated,load pick-up capability portion of this analysis,both units at Bradley Lake were modeled as being on-line as well as the Cooper Lake hydro units.The Cooper Lake units were modeled as being at full output,and the Bradley units supplied the remainder of the Kenai area load.The response of the system was measured following the addition of various amounts of load. For the 72 second alternative,the simulations demonstrated that the pick-up of 3 MW of load will cause the Kenai frequency to dip to about 59.1 Hz.This is a little above the first underfrequency relay load shedding point (58.8 Hz)being considered for the Kenai.When the load pick-up amount is increased to 5 MW, the frequency dips below the 58.8 Hz point,but stays above the 58.5 Hz trip point for the Tesoro refinery.A load pick-up of 7 MW will result in the Kenai frequency dipping to around 58.3 Hz. For the 30 second alternative,the simulations demonstrate that the load pick- up capability of Bradley will be worse than for the 72 second governor.This is due to the drop in head associated with the rapid opening of the needles. 3 MW of load pick-up will cause the Kenai frequency to dip to about 58.6 Hz,only slightly above the Tesoro refinery trip point.A 7 MW load pick-up will result in Kenai frequency dipping below 58.0 Hz.The faster needle valve opening rate with the existing hydraulic design worsens Bradley's response under isolated system conditions.The rapid needle opening rate causes the head pressure at the turbine to drop such that the power output of Bradley declines during the first few seconds of needle opening.This loss of power output compounds the problem of picking up load.For example,Bradley's response to a 3 MW increase in load causes the units'mechanical power output to decrease by about 7 MW (initially)making this equivalent to a 10 MW load pick-up.It takes six seconds following the load addition for Bradley's output to recover to the pre- disturbance level. When the 10 second alternative is considered,the load pick-up capability of Bradley Lake is significantly improved.A 3 MW increase in load for this hydraulic configuration only causes the Kenai frequency to dip to 59.6 Hz.A 7 MW increase in load will result in the frequency dipping to around 59.2 Hz. The simulations indicate that this hydraulic configuration will accommodate a load pick-up of approximately 10 MW (approximately the Seward Winter peak load). A 10 MW load increase causes the Kenai frequency to dip to or just above 58.8 Hz,the first underfrequency load shed point being considered for the Kenai area. 6.4 Summary of Results 6.4.1 Anchorage/Kenai Intertie Intact °With Combustion turbine spinning reserve available adequate to cover thelostgeneration-no load shedding is expected for Bradley needle openingtimesof10,30,and 72 seconds. 00974.wpf 2B 0470690 With Combustion turbine spinning reserve significantly less than the lost generation,the frequency drops below the first load shedding step for Bradley needle opening times of 10,30,and 72 seconds. Bradley 30 second load acceptance rate has a detrimental affect on frequency drop within the initial 2 seconds after the loss of generation as compared to the 72 second needle opening time. Frequency recovery is enhanced by the use of shorter needle opening times. When the amount of Combustion Turbine spinning reserve is significantly less than the lost generation,and if underfrequency load shedding is not implemented,the system frequency decays below all load shedding points for the Bradley 30 and 72 second needle opening times.Some load shedding is avoided with the 10 second needle opening time. When the amount of Combustion Turbine spinning reserve is significantly less than the lost generation,and if underfrequency load shedding is not implemented,the system frequency drops but remains above 59 Hz for the Bradley 10 second needle opening time thus avoiding most load shedding. Loss of Anchorage/Kenai Intertie Regardless of Bradley 10,30,or 72 second needle opening time,the system frequency drops below the lowest load shedding point and all load is shed. Bradley generators may be tripped off line due to underfrequency. With Bradley off line and two combustion turbines operating on the Kenai, undefrequency load shedding occurs,but not all load is lost. Kenai System Isolated (Only Bradley Lake and Cooper Lake on Line) For the Bradley 72 second Needle Opening Time -3 MW feeder pickup -frequency remains above first load shedding point -5 MW feeder pickup -frequency drops below first load shedding pointbutstaysabove58.5 Hz trip point for the Tesoro Refinery Bradley 30 Second Needle Opening Time -3 MW feeder pickup -frequency drops to about 58.5 Hz possibly sheddingmostorallofKenaiload -7 MW feeder pickup -frequency drops below 58.5 Hz shedding all KenailoadandtrippingBradleygenerations Bradley 10 second Needle Opening Time -3 MW feeder pickup -frequency drops to about 59.2 Hz avoiding all Kenailoadshedding -10 MW feeder pickup -frequency drops to 58.8 Hz the first underfrequency load shedding point for the Kenai 00974 .wpf 27 04/09/90 6.4.4 Spinning Reserve Contribution The Bradley Lake units can provide spinning reserves at all three needle opening times studied.The amounts are summarized below. SPINNING RESERVE BENEFIT Combustion scceee Rapid Load Acceptance ---------Turbine Peak Needle Interconnected System Kenai Isolated Rating Spinning Opening Time Lost gen -CT spin Reserve Enabled 72 seconds 27 MW 3 MW 90 MW * 30 seconds 27 MW O MW 90 MW * 10 seconds 45 MW 10 MW 90 MW * *Based on minimum head with two units.At maximum head with two units,112 MW is available. Rapid Load Acceptance When the Kenai and Anchorage systems are interconnected,and when the Kenai is isolated with only hydroelectric generation on line,all three needle opening times provide some spinning reserve for rapid load acceptance.However,due to head drop associated with the fast needle movement,the 30 second time was a negligible spinning reserve benefit under isolated system operation.The rapid response spinning reserve capabilities of Bradley Lake are summarized as follows. .Spinning Reserve Interconnected System Kenai Isolated Needle Opening Time Lost gen -CT spinnin es (Largest feeder picked up) 72 seconds 27 MW 3 MW 30 seconds 27 MW O MW 10 seconds 45 MW 10 MW The above spinning reserve values are the minimum available,provided that at least that much generation is available at Bradley Lake. Reduction of Combustion Turbine Load All three needle opening times allow the load of the combustion turbines to be substantially reduced within the first minutes after a disturbance.The amount of this type of spinning reserve available is the same for all needle openingtimesstudied,and equates to the full available rating of the Bradley Lakeunits.The only difference between the alternatives is the total lapsed time to achieve the full rating output.Load acceptance curves show that full outputfromtheturbinescanbeachievedasshownbelow. 00974 .wpf re 28 ae 04/11/90 Time To Full Load eedle enin me (From Speed-no-Load) 72 seconds 80 seconds 30 seconds 40 seconds 10 seconds 13 seconds* *Power output drops to 85%power by 70 seconds,recovering to 100%by 140 seconds. Since the units respond within 90 seconds for all three alternatives,operation of the combustion turbines up to their peak rating (assumed to be 10%over base rating)would be possible for all needle operating scenarios.Based on this, the addition of the Bradley Lake units can reduce the spinning reserve requirement from combustion turbines by as much as 100 MW (based on units at speed no load,and a 100 MW system spinning reserve requirement).This spinning reserve contribution,however,may be limited by the power transfer capability of the Anchorage-Kenai intertie. 00974.wpf 29 04/06/90 7.0 COST IMPACTS OF ALTERNATIVES 7.1 General Order of magnitude cost estimates were made for various surge tanks and the air chamber.In addition,costs of potential turbine and governor modifications as required to achieve various needle opening times were estimated.These estimates form the basis of the cost of the three alternatives considered in this study. The estimates include an average 15 percent indirect cost allowance to cover construction management,engineering,vendor design,owner costs =and miscellaneous costs.In addition,the estimates include a 20 percent contingency.The estimates do not include costs for schedule delays and loss of power due to a decision for the installation of surge tank(s)and resulting equipment modification. 7.2 Surge Tanks and Air Chamber Unit prices used for the cost estimates are based on the bid prices given for the General Construction Contract.The estimated costs for construction of the various surge tanks are as follows: Direct Indirect Total Construction Construction Construction Cost Cost Cost ion (SMillion)($Million) Air Chamber 26.1 3.9 30.0 Surge Tank No.1 14.2 2.8 17.0 Surge Tank No.2 9.7 1.9 11.6 Surge Tank No.3 1.3 0.3 1.6 These costs are used to develop the costs of the alternatives used in this study as shown in Table 2. 7.3 Turbine and Governor Modifications Cost estimates were developed for anticipated equipment modification as would be required to accommodate faster needle opening times.These estimates are based on the assumption that a decision to proceed with the modifications is made before concreting of the turbine pit liner and turbine head cover commences. The basic difference between the equipment modifications to suit a 10 second and a 20-second effective needle opening is that an increase of the governor oilpressurewouldberequiredforthe10secondalternative. The following costs have been estimated for various effective needle openingtimes,and are for costs for modifying the present two units. eedle Opening Time Estimated Costs 10 seconds $2.0M 20 seconds $1.6M 30 to 72 seconds $1.2M 72 seconds and more No additional cost 00974.wpf -=2 a.30 ae ---.04/09/90 8.0 CONCLUSIONS AND RECOMMENDATIONS 8.1 Conclusions The primary contribution of Bradley Lake as spinning reserve is derived by enabling the operation of combustion turbines at their peak rating for short durations to avoid frequency decay.Bradley Lake can accept load in less than 90 seconds up to its full capacity rating (nominally 90 MW)and back the combustion turbines down below their base rating. The use of decreased needle opening times below the existing 72 second needle time,facilitated by surge tanks or other means,does little to avoid load shedding or to increase the combined spinning reserve capability of Bradley Lake. The small increase in rapid response spinning reserve value,and other minor improvements in frequency control,do not appear to justify the added expense for the required modifications. Possible limitations to the amount of rapid response available exist:1)Placing as much as 50%(based on a 100 MW requirement)of the system spinning reserve at a remote power plant at the end of a long single transmission line, 2)Limitations in power flow on the transmission line,and 3)Possibly operating at lower efficiencies,spilling water to maintain the necessary available generation.These considerations indicate that an increase in rapid response spinning reserve from 27 MW to 45 MW may have little benefit. An additional governor operating mode providing simultaneous operation of allsixneedlesandallowingforpossibledeflectorrun-in will improve unit response and provide added frequency control when Bradley Lake or the Kenai is operatingisolated.This governor modification can be made at little expense. During Kenai import conditions,in order to avoid a collapse of the Kenai systemuponthelossoftheexistingAnchorage-Kenai intertie,combustion turbines must be operated on the Kenai Peninsula regardless of the Bradley Lake needle openingtimes. 8.2 °Recommendation 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 deflectors cut into the water stream. Discontinue any further investigation of revised needle opening times or modifiedhydraulicsystemdesignincludingsurgetanks. 00974 .wpft 31 04/06/90 ALASKA ENERGY AUTHORITY BRADLEY LAKE HYDROELECTRIC PROJECT LOAD ACCEPTANCE STUDY Effec- Nominal tive Needle Needle Needle Press Run No.of Opening Opening Opening Upper Accept- No.Units Time Time Rate Elbow ability (sec).(sec)(mm/sec)(ft) BASE CASE (NO SURGE TANK) D31 3 90.0 72.4 2.33 1060 accept D32 2 90.0 72.4 2.33 1066 accept co3 3 60.0 48.3 3.50 1052 accept D21 3 37.3 30.0 5.63 1038 unaccept D26 2 37.3 30.0 5.63 1050 accept SURGE TANK No.1 (STA 36463);Dia =40 ft;Riser Dia =13 ft DO3 3 12.4 10.0 16.90 1015 unaccept pos 2 12.4 10.0 16.90 1034 unaccept DO2 3 24.9 20.0 8.45 1045 marginal Dog 2 24.9 20.0 8.45 1057 accept SURGE TANK No.1 (STA 36463);Dia =40 ft;Riser Dia =20 ft DOs 3 12.4 10.0 16.90 1037 unaccept Do1 2 12.4 10.0 16.90 1051 accept SURGE TANK No.2 (STA 68+78);Dia =25 ft;Riser Dia =13 ft D13 3 12.4 10.0 16.90 1015 unacceptD15s212.4 10.0 16.90 1035 unaccept Dil 3 24.9 20.0 8.45 1046 marginal D14 2 24.9 20.0 8.45 1057 accept SURGE TANK No.3 (STA 184+76);Dia =11 ft:No riser D421 3 24.9 20.0 8.45 1041 unaccept SURGE TANK No.2 AND No.3 DSs1 3 12.4 10.0 16.90 1062 accept DS2 2 12.4 10.0 16.90 1069 accept NOTES: 1.All cases simulate full load acceptance.2.Initial reservoir level for all cases is at E1.1080°. 3.Effective needle stroke is 169 mn, nominal stroke is 210 mn. TABLE 1:LIST OF CASES ALASKA ENERGY AUTHORITY BRADLEY LAKE HYDROELECTRIC PROJECT LOAD ACCEPTANCE STUDY Direct Construc- tion Cost ALTERNATIVE (needle opn'ng time)|($Million) ALTERNATIVE I (72 seconds) Current Design 0.0 ALTERNATIVE II (30-72 sec) Equipment Modification 1.2 ALTERNATIVE III (10 seconds) Surge Tank No.2 9.7 Surge Tank No.3 1.3 Equipment Modification 2.0 TOTAL FOR ALTERNATIVE III 13.0 Indirect Construc- tion Cost ($Million) TABLE 2:COST OF ALTERNATIVES Total Construc- tion Cost ($Million) oOiWsels<3 $ |8 oie 2 318 2s12,g|F Fr OF 3 OFS =F mw |GATE SHAFT Se a B elt r:S ald |ra Fa >SleINTAKEoeDeos3«|¥ip) |\EL 1300"1 |1 TI G EL 1035.5 [ --4]k EL 1100 = |19 FT.J .© DIA.¢EL 309 | 1 7 /pb!¢EL 15 CONCRETE LINED SECTION yp |STEELLINED SECTION.| 11 FT.13 FT.DIA.11 FT.DIA.OFT. DIA.DIA. FIGURE 1:POWER TUNNEL PROFILE 41189134 EL 185 (TYP) HOUSE eT[aN NIRS 4"STEEL PLATE (TYP)- (|>COMPRESSOR i - | 30 FT DIA (TYP)"ACCESSSHAFTEL 50.0°(TYP) ee Renae /8 4 \ROCKoe EXCAVATION 50 X 90 FEET PUMPS SUMP ZL POWER TUNNEL11°DIA FIGURE 2:AIR CHAMBER V1189143 EL 1270° | 2B |ata EL 1220 3! i:EL 1180' i BUTTRESS (TYP) 2 5'THICK . i | im 4 EL 1100" -ATS |TSI |9RSS AS|Ss rrr|=g EL 1190 P| || _angTT ' 40°DIA.| | 2 LINER -=H-e EL 950° 13° 6id-_-rT1LINER=1 LINER EL 74 83'A --13'S -Eee eee eee er FIGURE 3:SURGE TANK NO.1 M41169129 EL 1330° EL 1300° VATS EL 1290° _- t-2°LINER :EL 900°\\LL -|1 LINER )A £13"DIA Y |EL 114"_0) ) FIGURE 4:SURGE TANK NO.2 °A1189130 "ca UPPER POWER TUNNEL EL 1290" EL 1270' M1189142 FIGURE 5:SURGE TANK NO.3 --_-POWERTUNNEL VERTICAL SHAFT D32:2-UNIT OPER;72-S FL-ACC;HWL=1080 NO SURGE TANKS 60 = a 50 =VA=Nw E 40 Zz 5 &/a.L _30 7ps > 3 /ec 20ulwl 4 ro) °/10 / 0 A 0 2 40 60 80 100 120 140 160 180 TIME (SECONDS) FIGURE 6:POWER RAMPING CURVE FOR ALTERNATIVE | D26:2-UNIT OPER;30-S FL-ACC;HWL=1080 NO SURGE TANKS 60 /\ 50 =/ =/Ee 40 = > é /a.Li36 > &/pm) ° &20 = ° a 16 0 20 40 60 80 100 120 TIME (SECONDS) FIGURE 7:POWER RAMPING CURVE FOR ALTERNATIVE II D52:2-UNIT OPER;10-S FL-ACC;HWL=1080 S-TANK £2:D=25FT;9 S=<TANK #3:D=tiFT 50 Sr eer 60 30 [ 10 / 0 20 40 60 80 100 120 TIME (SECONDS)POWEROUTPUTPERUNIT(MW)FIGURE 8:POWER RAMPING CURVE FOR ALTERNATIVE Il _ 00974.weE I-1 04/06/90___ APPENDIX I 1.0 METHODS FOR MITIGATION OF HYDRAULIC TRANSIENTS There are several methods or devices that can be used to control excessive or unacceptable hydraulic transients in a hydroelectric pressure tunnel.These include: Surge tanks Air chambers By-pass Valves Modification of WaterpassagesWH Undesirable transient conditions include excessive pressure rise,excessive pressure drop,water column separation,or turbine overspeed.The transient control devices are usually expensive and no single device is suitable for all hydraulic systems or for all operating conditions.Usually a number of alternatives are considered,electing the alternative that results in acceptable transient response conditions and provides the best overall economics for the plant. An acceptable transient response may be defined by specifying limits for maximum and minimum pressure changes within the power tunnel,maximum turbine speed following a load rejection,absence of subatmospheric pressure in any part of the waterpassages,or other specifics concerning the regulating characteristics of a hydraulic turbine.The regulating characteristics are usually discussed in terms of "water-starting time".The water starting time is approximately the time necessary to accelerate the entire mass of water in the waterpassages to its design flow velocity.The design flow velocity is designed as being the velocity achieved at the full power output of the turbine-generator unit when operating at maximum generating head.If the water-starting time can be reduced, the regulation characteristic of the power plant is improved. The following describes the methods used to control hydraulic transients. SURGE TANKS 1.1 Definition A surge tank is an open shaft or standpipe which is connected to the power tunnel at one end and is open to atmosphere on the other end.The surge tank provides (1)an intermediate reservoir to contain or provide a source of water during a load change,(2)a free water surface to facilitate reflection of part of the pressure waves generated within the flow passages by the load changes. 1.2 Surge Tank Functions The surge tank provides three functions: 1.Reduces pressure fluctuation amplitudes at the turbine inlet by acting to reflect incoming pressure waves from any downstream flow disturbance.In effect,placing a surge tank in a power conduit acts to shorten the distance a pressure wave travels from the turbine to the reservoir. 2.A surge tank can improve the regulating characteristics of a hydraulic turbine-generator unit.This is done by effectively reducing the waterstartingtimeofthewatercolumninthetunnelbyshorteningthelengthoftunnelbetweentheturbineandthenearestfreewatersurface. 00974 .wpft T-2 04/06/90 A surge tank acts as a storage reservoir of water and helps to deceleratethewatercolumninthepowertunnelduringapowerplantloadrejection. Similarly,it acts as a source of water during load acceptance.Thus,thewaterwithinthepowertunnelcanbeacceleratedordeceleratedmoreslowly which limits the pressure drop/rise extremes at the cost of increased head fluctuation within the power tunnel. 1.3 Types of Surge Tanks Surge tanks can be described as simple,orifice,differential,one-way,or closed. 1.Simple The simple surge tank is a vertical standpipe or shaft of constant diameter.A modified simple surge tank with a smaller diameter riser discharging into a larger diameter surge tank bowl on the top is commonly used for high head applications. Orifice The orifice type has a restriction at the surge tank entrance or exit into the power tunnel.Usually the restriction is circular and of limited height.If required,the restriction can be designed such that the head loss is higher for water flowing into the tank than for water flowing out of the tank or vice versa. Differential The differential surge tank is similar to the orifice type.In addition to an orifice it has a smaller diameter standpipe within the larger diameter surge tank bowl.The stand pipe has to be filled with water before water can overflow the top of the standpipe into the tank bowl. The water column in the standpipe acts as an additional entrance restriction into the surge tank.Usually a small orifice or opening at the bottom of the standpipe is provided to allow limited water flow from the power tunnel directly into the anulus between the surge tank bowl and internal standpipe and back. One-Way The one way surge tank is similar to a modified simple surge tank.In addition,a check valve is placed into the riser so that flow is allowed in only one direction. Closed The closed surge tank has a cover on the top of the tank bowl.A small opening (or pipe,shaft)is provided through the cover. Alternatively,a throttling valve can be placed into the opening and restrict surges in the tank by means of air entrapped in the tank. 00974 .wpf-.-----Hee eB 04706790 2.0 AIR CHAMBERS Air chamber construction is similar to that of a simple surge tank except that air chambers are fully enclosed and pressurized.The overall height of an air chamber is considerably less than that of a simple surge tank. During normal operation approximately one third of the air chamoer volume is filled with water and the remainder is filled with compressed air.Compressors must be provided to maintain the water and air volumes in the chamber in equilibriun. The function of an air chamber is similar to that of a simple surge tank.An air chamber is normally used where a surge tank would become a too tall free standing structure,difficult to support laterally.The air in the enclosed chamber forms a spring and acts as a substitute for the pressure that would have been naturally created by an equivalent free standing water column. 3.0 BY-PASS VALVES Partial or full flow by-pass valves are used to by-pass turbine flow followingaloadrejection.Simultaneous turbine closure and full by-pass valve opening would not change the flow rate in the power tunnel and thus will not create any pressure transient.The by-pass valve then closes at a very slow rate to minimize pressure variation in the power tunnel. Partial flow by-pass valve will operate similarly as the full flow by-pass valve.Since this valve can pass only part of the turbine flow,the flow rate in the tunnel following a full load rejection will be reduced and cause a lower pressure rise. A turbine with a full flow by-pass valve will operate similarly as a Pelton turbine with deflectors.Rapid load rejection will be possible,however the load acceptance rate will be restricted by the configuration of the power tunnel. 4.0 MODIFICATION OF WATERPASSAGES The amplitude of pressure fluctuations is dependent on the water starting time which is a direct function of the conduit length and velocities and inverse function of the head.Reduction of the water starting time would mean reduction of pressure fluctuations.Shorter water starting time could be achieved by anyofthefollowingsteps: 1.Lowering flow velocities in the tunnel by enlarging the flow section areas. 2.Reducing the overall length of waterpassages. 3.Increasing the turbine head by raising the reservoir level and/or lowering the powerhouse setting and tailwater level. 00974.wpf 1-4 04/06/90 USE OF COMBUSTION TURBINE PEAK RATING TO UTILIZE SPINNING RESERVE AT BRADLEY LAKE The following is a discussion of the use of combustion turbine (CT)peak ratingtoimproveutilizationofspinningreserveatBradley.It was prompted bydiscussionswithRailbeltutilityrepresentativesindicatingthattheyarewillingtoconsideroperatingCTsin"peak mode"in order to facilitate use of Bradley Lake spinning reserve. Most combustion turbines have,or can be modified to have,several "ratings” based on a utility's system needs and its perception of acceptable performance characteristics and costs associated with operation of a CT.Moreover,these ratings are not single values,but rather a set of values which are a functionoftheoperatingenvironmentoftheCT.Further,these ratings are established only for steady-state operating conditions.Speed controls associated with aCTcancausetheoutputtoexceedthesteady-state rating for a period of a few seconds in response to below-normal frequency excursions. Combustion turbines are typically rated based on a maximum allowable turbine exhaust gas temperature.CT ratings are usually established for a standard set of environmental operating conditions known as ISO conditions.ISO conditions refer to an ambient temperature of 59 degrees Fahrenheit,at normal sea-level atmospheric pressure and at a certain relative humidity.For ISO conditions, CTs will typically have two ratings based on some defined value of turbine exhaust gas temperature: 1)Base Rating 2)Peak Rating The turbine exhaust gas temperature is a significant indicator of the amount of life expenditure that occurs in a CT due to erosion and fatigue of the internal turbine parts. The base rating is the power rating at which a CT can operate for sustained periods of time and stay within what is considered to be a normal maintenance schedule and without severe or unusual degradation to the internal parts of the turbine.The peak rating is a power rating greater than the base rating at which a CT can operate for some limited period of time (hours),but which will cause greater than normal degradation of the internal parts of the turbine and will increase the frequency and necessity of maintenance. Although not specified as a rating,CTs have an emergency capability which is above the peak rating.This emergency capability may correspond to the maximum, physical fuel consumption capability of the turbine as allowed by the fuel control system.A CT can operate at this emergency capability for only a very limited period of time,and operation at such levels (for more than a few seconds consecutively)will result in severe degradation of the internal parts of the turbine and will require significant maintenance activity. As noted,CT ratings are established for 180 conditions.Of the factors defined by ISO conditions,the ambient temperature has the most significant affect on the rating of a CT.As the ambient temperature drops below the ISO condition level,a given amount of fuel flow into a CT will result in a lower turbine exhaust gas temperature.Therefore,one can inject more fuel into a CT at a lower ambient temperature without exceeding some prescribed level of turbine exhaust gas temperature.Conversely,as the ambient temperature goes above the 00974 .wpft II-2 04/06/90 ISO condition level,a given amount of fuel flow into a CT will result in ahigherturbineexhaustgastemperature.Thus,fuel flow into the CT must bedecreasedinordertonotexceedtheprescribedlevelofturbineexhaustgas temperature.Since the power output of a CT is a direct function of the fuelflowintoit,it becomes apparent that a CT will have a different base and peak rating for different ambient temperature conditions if one maintains a constant turbine exhaust gas temperature. Since turbine exhaust gas temperature is a critical factor in the operation of a combustion turbine,the controls of a CT are often designed to monitor this exhaust gas temperature and reduce the output of the CT when it exceeds some permissible exhaust gas temperature limit.This is accomplished through the use of a thermocouple in the exhaust gas stream.Such devices typically have a response time a several seconds and respond slowly to changes in exhaust gas temperature.In normal operation,the governor or other controls on a CT may increase the fuel flow into a combustion turbine in order to increase its output. Such increases can be up to the turbine's emergency capability (maximum fuel consumption level)and can boost the exhaust gas temperature above the permissible limit as defined by the particular rating (i.e.,base or peak). Therefore,a CT can exceed its rating until the controls respond to the elevated exhaust gas temperature,reduce the fuel flow and thus lower the output of the CT.Several seconds of "above rated power"output can be obtained from a CT during below-normal frequency excursions due to this operating characteristic. Based on the above descriptionof combustion turbine operation,various operating strategies can be developed to obtain increased response capability from a CT. One could normally operate a CT at no more than its base rating level and,during below-normal frequency conditions,take advantage of the few seconds of temporary "above rated power"output which might occur before the controls reduce the output of the CT back to its base rating level.Conversely,one could normally strive to operate a CT at no more than its base rating level,but configure the controls of the CT to allow it to operate,on a sustained basis,up to its peak rating level.Thus,in response to a below-normal frequency condition,the governor could boost the output of the CT to the emergency capability (maximum fuel consumption)until the exhaust temperature controls bring the output back to the peak rating level.The CT could then be allowed to operate at the peak rating level until other generation was brought on-line or until the output of slower responding hydro or steam units could be increased.Thus,the latter strategy would provide more sustained reserve capability from a given combustion turbine than the first operating strategy.Further,provided that a CT was not allowed to remain at its peak rating level for inordinate amounts of time,severe degradation of the internal parts of the turbine couldbe minimized and excessive maintenance activity avoided. One potential method of implementing the latter described control strategy would be to employ the use of a relay which would respond to below-normal frequency operation.The combustion turbine controls would normally be set to limit the turbine output based on the exhaust gas temperature associated with the turbine's base rating.Upon the occurrence of some predefined below-normal frequency (say 59 Hz)which existed for some length of time (say one second),the relay could switch the combustion turbine controls to limit the output of the turbine based on the exhaust gas temperature associated with the turbine's peak rating.Some form of control (i.e.,SCADA)could be used to allow an operator to reset the relay and reconfigure the controls to limit the turbine output based on the exhaust gas temperature associated with the turbine's base rating. 00974 .wpf a TTB __......04/06/90 The affects of this strategy on the operation of the Railbelt System is bestdemonstratedbywayofthefollowingexample.This example compares theoperationoftheexistingsystemwiththatofthefuturesystemwithBradleyLakeon-line.This example assumes a system load level similar to the 1988/89 WinterPeakwithgenerationdispatchaswasmodeledintheRailbeltUnderfrequencyLoadSheddingStudyforthewinterpeaknormaldispatchcase.As shown in the tablebelow,the existing system was calculated to have 86.5 MW of spinning reserveavailablefromcombustionturbinesassumingthattheCTswerelimited(on a sustained basis)to their winter base rating.For the future system,Bradley was assumed to be on-line at 60 MW.This allowed shutting off three CTs (Bernice Lake #3,AMLP #1 and Soldotna)and reducing the output of three other CTs by a total of 26.5 MW.In addition,this scenario assumes that all CTs which remained on-line could operate on a sustained basis up to their winter peak rating (i.e., 10%above the winter base rating)thus providing an additional 46.2 MW of reserve capability.As is shown in the table,the total spinning reserve available from the CTs is now 110.5 MW despite the fact that 60 MW of Bradley generation allowed the removal of three partially loaded CTs which previously provided spinning reserve capability.Moreover,Bradley Lake has 60 MW of reserve capability which,allowing sufficient time,could be increased if needed following a resource deficiency. Existing System Bradley On @ 60 MW Spinning Reserve Spinning Reserve Based On CT Winter Based On CT Winter System Load Base Ratings Peak Ratings Winter Peak 86.5 MW 110.5 MW In this example,economic operation is improved by taking lightly loaded CTs in the Kenai off line.A simpler scenario may be useful and representative of the future when "must run"units may not be operating in the Kenai (see the attached sketch).In (a)Bradley is off and 400 MW of CTs (base rating)are on-line and operating at 300 MW (there is 100 MW of spinning reserve on the CTs).In (b) Bradley is brought on-line at 60 MW,and an 80 MW CT (loaded to 60 MW)is removed.There is now just 80 MW of spinning reserve on the CTs.Bradleygoverningisassumedtobetooslowtohelpreduceloadshedding.*The result is a loss of 20 MW of spinning reserve.In (c)the CTs have been set to allow the units to go to peak rating when frequency drops due to a loss of generation. Assuming peak rating is 10%above base rating,this provides 32 MW of additional spinning reserve.This spinning reserve would come initially from the CTs and than from Bradley after about one minute.There is thus 112 MW of spinning reserve in this case.It is clear that additional CT capacity can be taken off line.In (d)an additional 10 MW of CT capacity is removed from the system. The 240 MW of CT loading is now spread among units with a total base rating of 310 MW,and a total capability of 341 MW at peak rating.There is 101 MW of spinning reserve in this case,70 MW between the initial CT operating points and base rating,and another 31 MW between base and peak ratings (10%of the 310 MW of on-line base capacity).In this scenario,bringing Bradley on-line at 60 MW and allowing CTs to operate up to peak rating when frequency is low,allows 90 2Studies of Bradley penstock performance presently underway indicate thatforthebasedesignwitha90secondneedlestroketimetheBradleypoweroutputwilldropfor6secondsbeforerecoveringtoitsinitiallevelandthen proceeding to a higher level when frequency drops. 00974 .wpf II-4 04/06/90 MW of (base)CT capacity to be taken off the system.Average loading of the remaining CTs rises from 75%to 77.5%for an additional economy. The amount of spinning reserve available in CTs will vary with load as units are put on-line and removed.It will range from marginal (say,100 MW)to an excess of 50 MW or so right after a unit is started up to avoid spinning reserve dropping below the minimum required (the excess will be equal to the base rating of the unit that is started).On average then,the spinning reserve will be well above the scheduled 100 MW minimum.Nonetheless,the capacity between base rating and peak rating can be used to reduce the average spinning reserve (between the operating point and base rating)when Bradley is on-line and has spinning reserve that is available to limit the duration of CT operation above base rating. In summary,the use of CT peak rating capacity following loss of generation can not only allow the system to utilize spinning reserve at Bradley,but can significantly improve economic operation. Though the emphasis here has been on facilitating use of Bradley Lake spinning reserve,the CT peak rating capability could be useful even when Bradley is off- line or is fully loaded and thus provides no reserves.CTs could be allowed to remain at peak rating until additional generation is brought on-line. However,the utilities indicate that due their reliance on the CTs for base power,the age of many of the CTs,and for control and operational reasons,they presently do not allow operation above the base rating,and would limit anyfutureuseatapeakratingtoonlyafewminutes. 00974 .wpf --1T-$000 Ct.04006790 1988 WINTER PEAK.30 MW NORTH, PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E 111.7 MW BASE RATE CT SPIN, RATOR SOMMARY:OADUWWYW691 998 4 NAME BSVLT # BELUGA3G13.8 BELUGASG13.8 BELUGA6G13.8 BELUGA7G13.8 BELUGA8G13.8 EKLUT 266.90 EKLOT 166.90 TEELAND 13.8 BERN 3G 13.8 BERN 4G 13.8 COOP1&2G4.20 FORT W.12.4 EIELSON 7.20 PUMP #8 24.9 FT GRELY4.16 UOFA 4.16 GLDRLSVS13.8 N.POLE 13.8 CHENA 12.5 CHENA 4.16 REALYSVS12.0 HEALY 1613.8 PLINT2 5613.8 PLNT2 6613.8 PLNT2 7613.8 PINT1 1613.8 TESORO1G24.9 SOLD SVS SOLDOT1G13.8 YSTEM TOTALS PHPPEPPPHNUNEUHHAANEHEHEHEEEEstNNNNNNNNNNNNNNNNNNNNNNNNYNWHWED, 45 MW SOUTH.BRADLEY OFF. 168.6 MW PEAK RATE CT SPIN. MW MVAR OMAX 68.0 0.6 24.8 55.0 0.6 33.0 65.7 70.5 37.1 78.0 -0.4 37.1 54.0 -0.1 30.0 16.0 3.6 7.3 16.0 3.6 7.3 0.0 -7.1 22.0 11.0 2.9 13.9 11.0 3.0 13.9 16.0 -1.8 14.7 14.2 3.9 10.8 15.0 $.9 8.2 0.3 0.0 0.0 0.7 0.0 0.0 9.0 4.5 7.0 0.0 14.4 33.0 48.0 0.7 34.8 15.0 6.6 12.2 1.0 0.0 0.0 0.0 -3.5 22.0 27.0 -0.2 15.5 35.0 17.0 17.1 34.0 6.1 20.5 77.0 38.1 49.7 5.90 5.7 9.4 4.0 1.9 1.9 0.0 8.9 30.0 6.0 -9.2 19.7 679.0 114.5 532.8 'i]iwteanwmworkayMmwooo©©©©©@mnooornhouwoVSCHED 1.0180 1.0180 1.0180 1.0200 1.0200 1.0200 1.0200 1.0200 1.0300 1.0300 1.0300 1.0400 1.0300 1.0000 1.0000 1.0300 1.0200 0.9860 1.0250 1.0000 1.0350 1.0140 1.0200 1.0200 1.0200 1.0200 1.0100 1.0200 1.0200 NOV 29 1989 1.0180 1.0180 1.0180 1.0200 1.0200 1.0200 1.0200 1.0200 1.0300 1.0300 1.0300 1.0400 1.0300 1.0145 0.9388 1.0300 1.0200 0.9860 1.0250 1.0183 1.0350 1.0140 1.0200 1.0200 1.0200 1.0200 1.0017 1.0200 1.0200 MVABASE= 10:43 VACTUAL REM 15 202 37 9989 1113.8 1988 WINTER PEAK.30 MW NORTH,4S MW SOUTH.BRADLEY OFF. 111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 Seconds. FILE:WP88NB01.CHN GOLD HILL 138 (HZ) 60.500 Hrs es rc sc ses x 56.000 BELUGA 138 (HZ) 60.500 rrr *>58.000 AMLP 230 (HZ) 60.500 @rwnrerernn=°58.000 SOLDOTNA 115 (HZ) 60.500 -77 7c 58.000 BRAOLEY 115 [H2) 60.500 ee 58.000 =|iT ||g a 2 x S 3 L- }= ; ? S 3 P 6 eo o SZZss = : TN ---_ ||e TUE,5.00007.00009.0000TIME3.00001.000014;353NOV281989BUSFREQUENCIES) PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED, NOV 29 1989 10:44 1988 WINTER PEAK. BRADLEY @ 40MW REPLACING HYDRO & STEAM. 111.7 MW BASE RATE CT SPIN, 168.6 MW PEAK RATE CT SPIN. RATOR SOMMARY: S$ NAME BSVLT #MAC TYP MW MVAR QMAX QMIN VSCHED VACTUAL REM 3 BELUGA3G13.8 68.0 . 24.8 -12.4 1.0180 1.0180 5 BELUGASG13.8 55.0 . 33.0 -16.5 1.0180 1.0180 6 BELUGA6G13.8 65.1 -0. 37.1 -11.1 1.0180 1.0180 7 BELUGA7G13.8 75.0 -0. 37.1 -11.1 1.0200 1.0200 8 BELUGA8G13.8 44.0 . 30.0 -15.0 1.0200 1.0200 24 EKLUT 266.90 16.0 . . -2.2 1.0200 1.0200 25 EKLUT 166.90 16.0 . . -2.2 1.0200 1.0200 34 TEELAND 13.8 0.0 0. 22. -22.0 1.0200 1.0200 15 67 BERN 3G 13.8 11.0 . 13. -6.9 1.0300 1.0300 68 BERN 4G 13.8 11.0 . 13. -6.9 1.0300 1.0300 79 COOP1&2G4.20 6.0 -0. 14. -9.2 1.0300 1.0300 121 FORT W. 12.4 14. . 10. -5.2 1.0400 1.0400 133 EIELSON 7.20 15. : ° -3.8 1.0300 1.0300 "10.2 1.0200 1.0200 -24.8 1.0200 1.0200 -4.7 1.0200 1.0200 "1.9 1.0100 1.0017 601 PLNT2 6613.8 602 PLNT2 7613.8 607 PLNT1 1613.8 691 TESORO1G24.9 4.25.0 8 136 PUMP #8 24.9 - 0.3 . . 0.0 1.0000 1.0143 145FT GRELY4.16 0.7 . . 0.0 1.0000 0.9386 151 DOFA 4.16 9.0 . -3.5 1.0300 1.0300 201 GLDHLSVS13.8 0.0 17. . -5.0 1.0200 1.0200 202 210N. POLE 13.8 48.0 . 7.4 0.9860 0.9860 213 CHENA 12.5 5.0 . . -4.0 1.0250 1.0250 214 CHENA 4.16 - 1.0 . . 0.0 1.0000 1.0183 368 HEALYSVS12.0 0.0 . 22. -33.0 1.0350 1.0350 37 370 HEALY 1G13.8 17.0 -0. 15. 7.5 1.0140 1.0140 503 BRAD EQV13.8 40.0 . 39. -39.3 1.0100 1.0100 600 PLNT2 5G13.8 35.0 16. 17. -8.5 1.0200 1.0200 24 . Lo) Lv) UNNNAUNNNNNNNNNNNNNNNNNANNNHNNNWDPY POLK WAHNHODHLAOANTDTROOHLOWNOWWODA0OA e ONWUKHMWADIHHROONAHRCODOOMOUDINOShb BPH RP HHH HEH HP HPN WNP WP Ee BNE Eee ee rPwWwNWOHPWOWOADHDUNDANHAWIOOMOLWWHJ !.KH YIOWLYUIUEFWUNOONDODDON@D0WOWW [} |ed QanoLu Wwoodod f 8 SOLD SVS . 30. -25.0 1.0200 1.0200 9989 4 SOLDOT1G13.8 . 0. 19. -5.9 1.0200 1.0200 aupoYSTEM TOTALS 678. 121. 572. -315.2 MVABASE= 1239.8 1988 WINTER PEAK.BRADLEY ©4OMW REPLACING HYDRO &STEAM. 111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FREQUENCY COMPARISON FOR DIFFERENT BRAOLEY HYDRAULICS. 10 SEC NEEDLE,SURGE TANK #1 60.500 FILE:WP88FO1.CHN Omer rere rrrrnbd $8.000 30 SEC NEEDLE,NO SURGE TANK 60.500 FILE:wWP88001.CHN . --------s 58.000 90 SEC NEEDLE.NO SUAGE TANK 60.500 FILE:WP88B01.CHN fe 58.000 [ae \|-T |3 \3 | _ \_ '\ \S Oo 4 ={- |.2 So =|_|é ro eo So | S Se oO -3 "ln 0.9.00007.0000$.00003.00001.0000oe-Pl cx o> ae|a="5ra]Sw _ w LL => x oO ree) rau a I = c uJ = - 1988 WINTER PEAK.BRADLEY ©YOMW REPLACING HYDRO &STEAM. 111.7 MW BASE RATE CT SPIN,168.6 MW PERK RATE CT SPIN. EXISTING BRADLEY HYORAULICS W/90 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING L11MW AT T =0.5 SECONDS. FILE:WP88B01.CHN GOLD HILL 138 fH2) 60.500 Messrs rccecs x 58.000 BELUGA 138 (HZ) 60.500 weer >58.000 AMLP 230 (HZ) 60.500 ewereeneee °58.000 SOLOOTNA 115 (HZ) 60.500 --TT 38.000 BRADLEY 115 (HZ) 60.500 --4 58.000 --10.0009.00006.00006.00004.00002.00000.0"94:TUE,5.00007.0000TIME3.00001.0000NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY @ 4YOMW REPLACING HYDRO &STEAM._111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN.>EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE.=TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS.=tdFILE:WP88B01.CHN WWos ce©ceANom TURBINE FLOW (CFS)dW. 1600.0 we cccr 100.00 =)2 TURBINE HEAD (FT)ff 1200.0 Power ecrrrr--°900.00 wd NEEDLE OPENING (PU)ra =| 1.0000 -_-_----S 0 fou jo ongPMECH(MW)oO150.00 0 |rt |: 'o t -o '8 s o =|2 :: 8 ?° i S ° S ,Qo ||_|® ° ;Sw a o -_2 =ry w - '- ;3 =:S 'fo) '4 é SoS= i 3 é /2 ,oO Le o 70 a i=] o”s -aa 2 i |L : 1988 WINTER PEAK.BRADLEY ©4YOMW REPLACING HYDRO &STEAM. 111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN.EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88001.CHN GOLD HILL 138 (HZ) 60.500 Mere cesses ses x 58.000 BELUGA 138 (HZ) 60.500 woot +SB.000 AMLP 230 {HZ) 60.500 ceiehaieteceeeketereted °58.000 SOLDOTNA 115 (HZ) 60.500 -------58.000 BRAOLEY 11S [HZ) 60.500 oe $8.000 10.0009.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.0000PY44NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY ©4YOMW REPLACING HYDRO &STEAM. 111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN. EXISTING BRAOLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. =0.5 SECONDS.TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T FILE:WP88D01.CHN TURBINE FLOW (CFS) 1600.0 oa +100.00 TURBINE HERD {FT} 1200.0 celeieeenenanenenetes °900.00 NEEDLE OPENING (PU) 1.0000 -Cr-nn Cd 0.0 PMECH (MW) 0.0 10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000015:39NOV281989BRADLEYPARAMETERS 1988 WINTER PEAK.BRADLEY @ YOMW REPLACING HYDRO &STEAM.111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN.BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE.TRIP AMLP UNITS #6 &#7 CARRYING L1iMW AT T =0.S SECONDS. FILE:WP88F01.CHN GOLD HILL 138 (42) 60.500 Morr recs css x 58.000 BELUGA 138 (HZ) 60.500 errr +58.000 AMLP 230 [HZ) 60.500 reer errr ernbd $8.000 SOLDOTNA 1!5 (HZ) 60.500 --_---<58.000 BRADLEY 115 (HZ) 60.500 &2)$8.000 |||10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000014:39NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY ©4YOMW REPLACING HYDRO &STEAM. 111.7 MW BASE RATE CT SPIN,168.6 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. &#7 CARRYING 1L1IMW AT T =0.5 SECONDS.TRIP AMLP UNITS #6 FILE:WP88F01.CHN TURBINE FLOW (CFS) 1600.0 eer roo +100.00 TUBBINE HEAD (FT) 1200.0 Poemrreresre °900.00 NEEDLE OPENING (PU) 1.0000 --7-777 0.0 PMECH (MW) 0.0 | -10.0009.00006.00006.00004.00002.0000TUE,5.00007.0000TIME3.00001.000016:03NOV281989BRADLEYPARAMETERS PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED,NOV 29 1989 10:44 1988 WINTER PEAK.BRADLEY @ 40MW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. RATOR SUMMARY: --S NAME BSVLT #QMIN VSCHED VACTUAL REM5s%%:MA 3 BELUGA3G13.8 1 2 68.0 -0.5 24.8 12.4 1.0180 1.0180 5 BELUGASG13.8 1 2 55.0 -0.3 33.0 16.5 1.0180 1.0180 6 BELUGA6G13.8 1 3 63.0 -1.6 37.1 11.1 1.0180 1.0180 7 BELUGA7G13.8 1 2 75.0 -1.7 37.1 -11.1 1.0200 1.0200 8 BELUGA8G13.8 1 2 36.0 -0.6 30.0 15.0 1.0200 1.0200 24 EKLUT 266.390 1 2 16.0 3.4 7.3 "2.2 1.0200 1.0200 25 EKLUT 166.90 1 2 16.0 3.4 7.3 2.2 1.0200 1.0200 34 TEELAND 13.8 1 2 0.0 -8.1 22.0 22.0 1.0200 1.0200 15 79 COOP1&2G4.20 2 2 16.0 "1.5 14.7 9.2 1.0300 1.0300 121 FORT W.12.4 4 2 14.2 3.9 10.8 5.2 1.0400 1.0400 133 EIELSON 7.20 4 2 15.0 5.9 8.2 -3.8 1.0300 1.0300 136 PUMP #8 24.9 1 -2 0.3 0.0 0.90 0.9 1.0000 1.0145 145 FT GRELY4.16 1 -2 0.7 0.0 0.0 0.9 1.0000 0.9388 151 UOFA 4.16 3 2 9.0 4.5 7.0 -3.5 1.0300 1.0300 201 GLDELSVS13.8 1 2 0.0 14.4 33.0 5.0 1.0200 1.0200 202 210 N.POLE 13.8 2 2 48.0 0.7 34.8 "17.4 0.9860 0.9860 213 CHENA 12.5 3 2 15.0 6.6 12.2 -4.0 1.0250 1.0250 214 CHENA 4.16 2 +2 1.0 0.0 0.0 0.0 1.0000 1.0183 368 HEALYSVS12.0 1 2 0.0 -3.5 22.0 -33.0 1.0350 1.0350 37 370 HEALY 1613.8 1 2 27.0 -0.2 15.5 -7.5 1.0140 1.0140 $03 BRAD EQV13.8 1 2 40.0 0.7 39.3 739.3 1.0100 1.0100 600 PLNT2 5613.8 1 2 35.0 16.3 17.1 8.5 1.0200 1.0200 601 PLNT2 6613.8 1 2 34.0 5.3 (20.5 -10.2 1.0200 1.0200602PLNT27613.8 Ll 2 77.0 37.1 49.7 24.8 1.0200 1.0200 607 PLNT1 1613.8 1 2 5.0 5.5 9.4 74.7 1.0200 1.0200 691 TESORO1G24.9 1 +2 4.0 1.9 1.9 "1.9 1.0100 0.9773 998 SOLD SVS 1 2 0.0 7.5 30.0 -25.0 1.0200 1.0200 9989 $994 SOLDOT1G13.8 1 2 6.0 -0.2 19.7 -5.9 1.0200 1.0200 YSTEM TOTALS 676.2 98.9 544.3 -301.4 MVABASE=1180.6 1988 WINTER PEAK.BRADLEY ©YOMW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FREQUENCY COMPARISON FOR DIFFERENT BRADLEY HYDRAULICS. 10 SEC NEEDLE,SURGE TANK «#1 60.500 FILE:WP88C01.CHN 60.500 FILE:WP88G01.CHN Or rr errrenn °38.000 30 SEC NEEDLE.NO SURGE TANK 60.500 FILE:WP88E01.CHN --TT 58.000 90 SEC NEEDLE,NO SURGE TANK &2 58.000 |||u |weeen4t 4 1} t LY 10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000010:40AMLP230KVFREQUENCY(HZ)NOV281989 1988 WINTER PEAK.BRADLEY @ 40MW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88C01.CHN GOLD HILL 138 fHZ) 60.500 Moerses x 58.000 BELUGA 138 (HZ) 60.500 heen +58.000 AMLP 230 (HZ) 60.500 a 3 58.000 SOLDOTNA 115 _(H7) 60.500 -----=58.000 BARDLEY 115 {HZ) 60.500 -<-$--s 58.000 ||10.0003.00008.00006.00004,00002.00000.0TUE,7.00005.0000TIME1.000014:49NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY ©4OMW.BERNICE 3 &&OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN.LwEXISTINGBRADLEYHYDRAULICSW/S0 SECOND NEEDLE STROKE RATE.=fTRIPAMLPUNITS#6 &#7 CARRYING 1L11MW AT T =0.5 SECONDS.=UJ FILE:WP88C0O1.CHN iTos ce©[oomaq TURBINE FLOW (CFS)jo 1600.0 eT TH =100.00]§z= TURBINE HEAD (FT)ff 1200.0 Seeiadeieieieteteetes °900.00 uw ed NEEDLE OPENING (PU)=o 1.0000 -_---_-A 0.0 om Cc-_PMECH (MW)o}150.00 e a 0.0 |rt ||g e. 3 !o T -¢ ° 3 t . Lo S 3 t s ,ss > SwLeeo- _°=i wow '- 3 -H _}¢ /o 's -'eo /"ss Ps /4 =/S /"7s a"eo __aa 3 R L ||e 1988 WINTER PEAK.BRADLEY @ YOMW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88E01.CHN GOLD HILL 138 (HZ) 60.500 Mrcr sessss x $8.000 BELUGA 138 (HZ) 60.500 rors +58.000 AMLP 230 (HZ) 60.500 ,cateieteheteeedenatel °S8.000 SOLDOTNA 115 {HZ) 60.500 --TT 58.000 BRACLEY 115 (HZ) 60.500 &is 58.000 ||| x L_--._ } - x 10.0009.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00004.0000W4H345NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY ©4OMW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING L1IMW AT T =0.5 SECONDS. FILE:WP88E01.CHN TURBINE FLOW (CFS) 1600.0 eer +100.00 TURBINE HEAD (FT) 1200.0 Peerrrrere °900.00 NEEDLE OPENING (PU) 1.0000 ------0.0 PMECH (MW) 150.00 .0.0 \\ Le \ \ \\ \ \\\\\ | \ = I i ||10.0003.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000015:40NOV281989BRADLEYPARAMETERS 1988 WINTER PEAK.BRADLEY @ 4YOMW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 1L11MW AT T =0.5 SECONDS. FILE:WP88G01.CHN GOLD Hitt 138 (Hz) 60.500 Meee sess x 58.000 BELUGA 138 (HZ) 60.500 errr +58.000 AMLP 230 (HZ) 60.500 rrr rect °$8.000 SOLDOTNA 115 (HZ) 60.500 ----oO 58.000 BRADLEY 115 (2) 60.500 SEES)58.000 _10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000014:40NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BRADLEY ©4OMW.BERNICE 3 &4 OFF. 83.7 MW BASE RATE CT SPIN,135.6 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88G01.CHN TURBINE FLOW (CFS) 1600.0 eer err +100.00 TURBINE HEAD (FT) 1200.0 Orr mtorr rrse °$00.00 NEEDLE OPENING (PU) 1.0000 -F-To 0.0 PMECH {MW) 150.00 _ -----_5 0.0 if vy ,I 4!| \ i \ jy - 1 \ =-10.0009.00006.00006.00004.00002.00000.0;ie7.0000TUE,BRADLEYPARAMETERS3.00001.000016:04NOV281989 PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED,NOV 29 1989 10:44 1988 WINTER PEAK.BRADLEY @ 46MW.BERN 3 &4,SOLDOTNA OFF. 49.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. RATOR SUMMARY: S NAME BSVLT #MAC TYP MW MVAR QMAX QMIN VSCHED VACTUAL REM 3 BELUGA3G13.8 1 2 68.0 -0.5 24.8 "12.4 1.0180 1.0180 5 BELUGASG13.8 1 2 55.0 -0.3 33.0 "16.5 1.0180 1.0180 6 BELUGA6G13.8 1 3 63.2 71.6 37.1 "11.1 1.0180 1.0180 7 BELUGA7G13.8 1 2 75.0 1.7 37.1 -11.1 1.0200 1.0200 8 BELUGA8G13.8 1 2 36.0 -0.6 30.0 -15.0 1.0200 1.0200 24 EXLUT 266.90 1 2 16.0 3.4 7.3 -2.2 1.0200 1.0200 25 EKLUT 166.90 1 2 16.0 3.4 7.3 72.2 1.0200 1.0200 34 TEELAND 13.8 1 2 0.0 "8.1 22.0 22.0 1.0200 1.0200 1s 79 COOP1&2G4.20 2 2 16.0 71.5 14.7 -9.2 1.0300 1.0300 121 FORT W.12.4 4 2 14.2 3.9 10.8 -5.2 1.0400 1.0400 133 EIELSON 7.20 4 2 15.0 §.9 8.2 -3.8 1.0300 1.0300 136 PUMP #8 24.9 1 -2 0.3 0.0 0.0 0.0 1.0000 1.0145 145 FT GRELY4.16 1 -2 0.7 0.0 0.0 0.0 1.0000 0.9388 151 0 OF A 4.16 3 2 9.0 4.5 7.0 -3.5 1.0300 1.0300 201 GLDHLSVS13.8 1 2 0.0 14.4 33.0 5.0 1.0200 1.0200 202 210 N.POLE 13.8 2 2 48.0 0.7 34.8 -17.4 0.9860 0.9860 213 CHENA 12.5 3 2 15.0 6.6 12.2 4.0 1.0250 1.0250 214 CHENA 4.16 2 -2 1.0 0.0 0.0 0.0 1.0000 1.0183 368 HEALYSVS12.0 1 2 0.0 -3.5 22.0 -33.0 1.0350 1.0350 37 370 HEALY 1613.8 1 2 27.0 -0.2 15.5 -7.5 1.0140 1.0140 503 BRAD EQV13.8 1 2 46.0 0.0 39.3 -39.3°1.0100 1.0100 600 PLNT2 5613.8 1 2 35.0 16.3 17.2 -8.5 1.0200 1.0200 601 PLNT2 6613.8 1 2 34.0 5.3 20.5 -10.2 1.0200 1.0200 602 PLNT2 7613.8 1 2 77.0 37.1 49.7 -24.8 1.0200 1.0200 607 PLNT1 1613.8 1 2 5.0 5.5 9.4 -4.7 1.0200 1.0200 691 TESORO1G24.9 1 -2 4.90 1.9 1.9 -1.9 1.0100 0.9773 998 SOLD SVS 1 2 0.0 9.3 30.0 25.0 1.0200 1.0200 9989 SUBSYSTEM TOTALS 676.4 100.4 524.6 -295.5 MVABASE=1135.3 1988 WINTER PEAK.BRADLEY ©46MW.BERN 3 &4,SOLDOTNA OFF. u9.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. TRIP AMLP UNITS #6 &#7 CARRYING LIIMW AT T =0.5 SECONDS. FREQUENCY COMPARISON FOR DIFFERENT BRADLEY HYORAULICS. 10 SEC NEEDLE,SURGE TANK #1 60.500 FILE:WP88G02.CHN ee °58.000 30 SEC_NEEDLE,NO SURGE TANK 60.500 "FILE:WP88E02.CHN -------= 58.000 90 SEC NEEDLE,NO SURGE TANK 60.500 FILE:WPS8CO2.CHN ----a 58.000 }4 ||y ||| AY \\ \ \ /\10.0009.00008.00006.00004.00002.00000.0244]10(HZ)TUE,5.00007.0000TIME3.00001.0000NOV281989AMLP230KVFREQUENCY 1988 WINTER PEAK.BRADLEY ©46MW.BERN 3 &4,SOLDOTNA OFF. 49.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYORAULICS W/90 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88C02.CHN GOLO HILL 138 (HZ) 60.500 one x 38.000 BELUGA 138 (HZ) 60.500 eforree +58.000 AMLP 230 (HZ) 60.500 errant ores °58.000 SOLOOTNA 115 (HZ) 60.500 --7-7-7 58.000 BRADLEY 115 (HZ) 60.500 i 58.000 x L__'- q 10.0009.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000014:50NOV281989BUSFREQUENCIES SOLDOTNA OFF.1988 WINTER PEAK.BRADLEY ©4Y6MW.BERN 3 &4, 49.7 MW BASE RATE CT SPIN,397.6 MW PEAK RATE CT SPIN.ie Jp)EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE TRIP AMLP UNITS #6 &#7 CARRYING L1IMW AT T =0.5 SECONDS.=WJ FILE:WP88CO02.CHN aTos cor c Cx TURBINE FLOW (CFS)a. 1600.0 -s>-----+100.00 oy|TURBINE HEAD (FT)tJ1200.0 Oana ce ne aeee °$00.00 ulJ[NEEDLE OPENING (PU)2a 1.0000 |0.0 c PMECH {MW}=150.00 S S)0.0 :t ---t °|'ial S \!Se|s -:r a '| '\° 'il S _+6 '\ >| -!a 'Su_;sa su. ; ;4 : -Pd 4° 4 -_|8 |3 1988 WINTER PEAK.BRADLEY @ 46MW.BERN 3 &4, 49.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 1L11MW AT T =0.5 SECONDS. FILE:WP88E02.CHN GOLD HILL 138 (HZ) SOLDOTNA OFF. 60.500 Merrscscsses x $8.000 BELUGA 138 (HZ) 60.500 le >58.000 AMLP 230 (HZ) 60.500 oem een arenan °58.000 SOLOOTNA 115 (HZ) 60.500 --7-7 58.000 BRADLEY 115 (HZ) 60.500 al a 58.000 10.0009.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.0000PYs45NOV281989BUSFREQUENCIES 1988 WINTER PERK.BRADLEY ©4Y6MW.BERN 3 & TRIP AMLP UNITS #6 &#7 CARRYING LIIMW AT T FILE:WP88E02.CHN TURBINE FLOW (CFS) 4,SOLDOTNA OFF. 49.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. =0.5 SECONDS. 1600.0 eer +100.00 TURBINE HEAD {FT} 1200.0 :iaheheieeheeietete °$00.00 NEEDLE OPENING (PU) 1.0000 -7-7 To 0.0 PMECH (MW) 0.0 10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000015:41NOV281989BRADLEYPARAMETERS 1988 WINTER PEAK.BRADLEY ©YEMW.BERN 3 &4, u9.7 MW BASE RATE CT SPIN,97.6 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88G02.CHN GOLD HILt 138 (Hz) SOLDOTNA OFF. 60.500 Reerccscccee x 58.000| BELUGA 138 (HZ)| 60.500 paaeieeieieteiaed +58.000| AMLP 230 (H7?) 60.500 ee °58.000 SOLDOTNA 115 (HZ) 60.500 --e-Or 58.000 BRADLEY 115 (H?) 60.500 ----58.000 10.0009.00008.00006.00004.00002.0000TUE,5.00007.0000TIME3.00001.000014340BUSFREQUENCIESNOV281989 1988 WINTER PEAK. 49.7 MW BASE RATE CT SPIN, BRADLEY ©46MW.BERN 3 &4, 97.6 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE Rave. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88G02.CHN TURBINE FLOW (CFS) SOLDOTNA OFF. 1600.0 eeoc-ce +100.00 TURBINE HEAD (FT) 1200.0 @orerercerrnn °900.00 NEEDLE OPENING (PU) 1.0000 --_---7 0.0 PMECH (MW) 150.00 a 0.0 my ||||10.0006.00006.00004.00002.00000.0SP ©iJ tuos ce © "a > o> tuLudead-2 c co 3 S Swv= -_ 2 =) to] s PTI INTERACTIVE POWER SYSTEM SIMULATOR -PSS/E WED,NOV 29 1989 10:45 1988 WINTER PEAK.BERNICE 3 &4,SOLDOTNA,&AMLP #1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. 'RATOR SUMMARY: QMIN VSCHED VACTUAL REM'S NAME BSVLT #MAC TYP MW MVAR QMAX 3 BELUGA3G13.8 1 2 68.0 0.0 24.8 -12.4 1.0180 1.0180 5 BELUGASG13.8 1 2 55.0 O.1 33.0 -16.5 1.0180 1.0180 6 BELUGA6G13.8 1 3 63.4 1.1 37.1 "11.1 1.0180 1.0180 7 BELUGA7G13.8 1 2 75.0 -1.1 37.1 "11.1 1.0200 1.0200 8 BELUGA8G13.8 1 2 36.0 -0.1 30.0 -15.0 1.0200 1.0200 24 EKLUT 266.90 1 2 16.0 3.7 7.3 -2.2 1.0200 1.0200 25 EKLUT 166.90 1 2 16.0 3.7 7.3 -2.2 1.0200 1.0200 34 TEELAND 13.8 1 2 0.0 -7.4 22.0 22.0 1.0200 1.0200 15 79 COOP1&2G4.20 2 2 16.0 "1.4 14.7 -9.2 1.0300 1.0300 121 FORT W.12.4 4 2 14.2 3.9 10.8 -5.2 1.0400 1.0400 133 EIELSON 7.20 4 2 15.0 5.9 8.2 -3.8 1.0300 1.0300 136 PUMP #8 24.9 1 =-2 0.3 0.0 0.0 0.0 1.0000 1.0145 145 FT GRELY4.16 1 -2 0.7 0.0 0.0 0.0 1.0000 0.9388 151 OU OF A 4.16 3 2 9.0 4.5 7.0 -3.5 1.0300 1.0300 201 GLDALSVS13.8 1 2 0.0 14.4 33.0 -5.0 1.0200 1.0200 202 210 N.POLE 13.8 2 2 48.0 0.7 34.8 717.4 0.9860 0.9860 213 CHENA 12.5 3 2 15.0 6.6 12.2 74.0 1.0250 1.0250 214 CHENA 4.16 2 -2 1.0 0.0 0.0 0.0 1.0000 1.0183 368 HEALYSVS12.0 1 2 0.0 "3.5 22.0 33.0 1.0350 1.0350 37 370 HEALY 1613.8 1 2 27.0 -0.2 15.5 -7.5 1.0140 1.0140 503 BRAD EQV13.8 1 2 $1.0 -0.6 39.3 -39.3 1.0100 1.0100 600 PLNT2 5613.8 1 -2 35.0 17.1 17.1 8.5 1.0200 1.0188 601 PLNT2 6613.8 1 2 34.0 6.7 20.5 710.2 1.0200 1.0200 602 PLNT2 7613.8 1 2 77.0 39.0 49.7 -24.8 1.0200 1.0200 691 TESORO1G24.9 1 -2 4.0 1.9 1.9 -1.9 1.0100 0.9773 998 SOLD SVS 1 2 0.0 9.6 30.0 -25.0 1.0200 1.0200 9989 SUBSYSTEM TOTALS 676.6 102.4 515.2 -290.8 MVABASE=1119.7 1988 WINTER PEAK.BERNICE 3 &4,SOLDOTNA,&AMLP #1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. TRIP AMLP UNITS #6 &#7 CARRYING L11MW AT T =0.5 SECONDS. FREQUENCY COMPARISON FOR DIFFERENT BRADLEY HYORAULICS. 10 SEC NEEDLE,SUAGE TANK «1 60.500 FILE:WP88G03.CHN ie =58.000 30 SEC NEEDLE,NO SURGE TANK 60.500 FILE:WPOGEO3.CHN SS =58.000 90 SEC NEEDLE,NO SURGE TANK 60.500 FILE:WPe8CO3.CHN o-----s___58.000 [Toy |toy ||| '\ '\10.0009.00006.00006.00004.00002.00000.0244210(HZ);a7.0000TUE,AMLP230KVFREQUENCY3.00001.0000NOV281989 1988 WINTER PEAK.BERNICE 3 &&,SOLDOTNA, 37.7 MW BASE RATE CT SPIN, &AMLP #1 OFF. 83.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE. #6 &#7 CARRYING 1L11MW AT T =0.5 SECONDS. FILE:WP88C03.CHN TRIP AMLP UNITS GOLD Hitt 138 {HZ} 60.500 Moreeeeeeeene x 58.000 BELUGA 138 (HZ) 60.500 errr *58.000 AMLP 230 (HZ) 60.500 ----------->58.000 SCLOOTNA 115 (HZ) 60.500 -7 7 7 $8.000 BRAOLEY 115 (HZ) 60.500 &3 58.000 K { ? .--10.0009.00006.00006.00004.00002.0000Oo.7.00005.0000TIMETUE,3.00001.000014:50NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BERNICE 3 &%&,SOLDOTNA, 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RAT &AMLP #1 OFF. E CT SPIN. EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE. =0.5 SECONDS.TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T FILE:WP88C03.CHN TURBINE FLOW (CFS) 1600.0 eon +100.00 TURBINE HEAD (FT) 1200.0 eee °300.00 NEEDLE OPENING (PU) 1.0000 -----=0.0 PMECH (MW) 0.0 6.00006.00004.00002.00000.3.0000TUE,7.00005.0000TIME1.000014:06NOV281989BRADLEYPARAMETERS 1988 WINTER PEAK.BERNICE 3 &4,SOLDOTNA,&AMLP #1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING L1IMW AT T =0.5 SECONDS. FILE:WP88E03.CHN GOLD HILL 138 (H2) 60.500 Merrcsescsee ®58.000 BELUGA 138 (HZ) 60.500 alee +58.000 AMLP 230 (HZ) 60.500 errrrererernn °58.000 SOLOOTNA 115 ([HZ) 60.500 --TT 58.000 BRADLEY 115 (HZ) 60.500 _|58.000 p---10.0009.00006.00006.00004.00002.00000.046BUSFREQUENCIESI:TUE,5.00007.0000TEME3.00001.0000NOV281989 1988 WINTER PEAK.BERNICE 3 &4,SOLDOTNA,&AMLP #=1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88E03.CHN TURBINE FLOW (CFS) 1600.0 i lee +100.00 TURBINE HEAD (FT) 1200.0 eet etaeetaas °900.00 NEEDLE OPENING (PU) 1.0000 --TT 0.0 PMECH (MW) 0.0 10.0009.00006.00006.00004.00002.0000Oo.TUE,5.00007.0000TIME3.00001.000015:42NOV281989BRADLEYPARAMETERS 1988 WINTER PEAK.BERNICE 3 &4,SOLDOTNA,&AMLP #1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88G03.CHN GOLD HILL 138 [H7) 60.500 Meer sce rsece x 58.000 BELUGA 138 (H2) 60.500 rere *58.000 AMLP 230 (HZ) 60.500 Owen cre r-==°58.000 SOLDOTNA 115 (HZ) 60.500 ---58.000 BRADLEY 1:5 (Hz) 60.500 &6 58.000 10.0009.00006.00006,00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000014:44NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BERNICE 3 &4,SOLOOTNA,&AMLP #1 OFF. 37.7 MW BASE RATE CT SPIN,83.9 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE ARATE. TRIP AMLP UNITS #6 &#7 CARRYING 1L11MW AT T =0.5 SECONDS. FILE:WP88G03.CHN TURBINE FLOW (CFS) 1600.0 rere +100.00 TURBINE HEAD (FT) 1200.0 @ne-ooocs 900.00 NEEDLE OPENING (PU) 1.0000 a 0.0 PMECH (MW) 150.00 -----0.0 t otiI |||||| ! : I eo {-_ \ I t \10.0009.00008.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000016:05NOV281989BRADLEYPARAMETERS PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E WED,NOV 29 1989 10:45 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA,AMLP #1,NP #1 OFF. 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. ERATOR SUMMARY:Us NAME BSVLT #MAC TYP MW VSCHED VACTUAL REM::3 BELUGA3G13.8 1 2 68.0 0.0 24.8 712.4 1.0180 1.0180 5 BELUGASG13.8 1 2 55.0 0.1 33.0 716.5 1.0180 1.0180 6 BELUGA6G13.8 1 3 63.8 -1.1 37.1 "11.2 1.0180 1.0180 7 BELOGA7G13.8 1 2 75.0 -1.1 37.1 11.1 1.0200 1.0200 8 BELUGA8G13.8 1 2 36.0 0.0 30.0 -15.0 1.0200 1.0200 24 EKLOT 266.90 1 2 16.0 3.7 7.3 -2.2 1.0200 1.0200 25 EKLUT 166.90 1 2 16.0 3.7 7.3 -2.2 1.0200 1.0200 34 TEELAND 13.8 1 2 0.0 -7.3 22.0 -22.0 1.0200 1.0200 15 79 COOP1&2G4.20 2 2 16.0 -1.4 14.7 -9.2 1.0300 1.0300 121 FORT W.12.4 4 2 14.2 4.2 10.8 -5.2 1.0400 1.0400 133 EIELSON 7.20 4 2 15.0 6.6 8.2 73.8 1.0300 1.0300 136 PUMP #8 24.9 1 =-2 0.3 0.0 0.0 0.0 1.0000 1.0169 145 FT GRELY4.16 1 -2 0.7 0.0 0.0 0.0 1.0000 0.9406 151 OU OF A 4.16 3 2 9.0 4.6 7.0 -3.5 1.0300 1.0300 201 GLDELSVS13.8 1 2 0.0 15.0 33.0 -5.0 1.0200 1.0200 202 213 CHENA 12.5 3 2 15.0 6.9 12.2 -4.0 1.0250 1.0250 214 CHENA 4.16 2 -2 1.0 0.0 0.0 0.0 1.0000 1.0183 368 HEALYSVS12.0 1 2 0.0 -3.2 22.0 -33.0 1.0350 1.0350 37 370 HEALY 1613.8 1 2 27.0 -0.2 15.5 -7.5 1.0140 1.0140 503 BRAD EQV13.8 1 2 51.0 -0.6 39.3 -39.3 1.0100 1.0100 600 PLNT2 5613.8 l -2 35.0 17.1 17.1 -8.5°1.0200 1.0188 601 PLNT2 6613.8 1 2 34.0 6.8 20.5 -10.2 1.0200 1.0200 602 PLNT2 7613.8 1 2 77.0 39.1 49.7 -24.8 1.0200 1.0200 691 TESORO1G24.9 1 =2 4.0 1.9 1.9 -1.9 1.0100 0.9773 998 SOLD SVS 1 2 0.0 9.6 30.0 -25.0 1.0200 1.0200 9989 SUBSYSTEM TOTALS 629.0 104.3 480.4 -273.4 MVABASE=1047.8 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA,AMLP #1,NP #1 OFF.25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN.TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FREQUENCY COMPARISON FOR DIFFERENT BRADLEY HYORAULICS. 10 SEC NEEDLE,SURGE TANK «#1 60.500 FILE:WP88G04.CHN reerereres °58.000 30 SEC NEEDLE,NO SUAGE TANK 60.500 FILE:WP88E04.CHN -7-TOs 58.000 90 SEC NEEDLE,NO SURGE TANK 60.500 FILE:WP88CO4.CHN SS 58.000 |fo oy ||Ns10.0009.00006.00006.00004.00002.00000.05.00007.0000TIME3.0000.1.000010:43NOV281989(HZ)TUE,AMLP230KVFREQUENCY 1988 WINTER PEAK. 25.7 MW BASE RATE CT SPIN, BERN 3 &4,SOLDOTNA,AMLP #1,NP #1 OFF. 65.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYDRAULICS W/90 SECOND NEEDLE STROKE RATE. =0.S SECONDS.TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T FILE:WP88CO4.CHN GOLD HILL 138 (H7) 60.500 Mrrsrrcsscss x 58.000 BELUGA 138 (HZ) 60.500 reer *38.000 AMLP 230 (H7) 60.500 .S ceketetebekadaeoetatetee °58.000 SOLODOTNA 115 (HZ) 60.500 --7-77 58.000 BRAOLEY 115 (HZ) 60.500 58.000 || -30.00024.00018.00012.0006.00000.015.0002t.00027.000TUETIME,9.00003.000014:52NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA, FILE:WP88CO4.CHN TURBINE FLOW (CFS) AMLP #1,NP #1 OFF. 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYORAULICS W/90 SECOND NEEDLE STROKE RATE.TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. 1600.0 errr 100.00 TURBINE HEAD (FT) 1200.0 O meeneeenwee °300.00 NEEDLE OPENING (PU) 1.0000 --TT 7 0.0 PMECH (MW) 0.0 | -30.00024.00018.00012.0006.00000.Tie.21.00027.000TUE,1989BRADLEYPARAMETERS9.00003.000015:28NOV28® 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA,AMLP #1, 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYORAULICS W/30 SECOND NEEDLE STROKE RATE. =0.5 SECONDS.TRIP AMLP UNITS #6 &#7 CARRYING L1IIMW AT T FILE:WP88E04.CHN GOLO HILL 138 [HZ) NP #1 OFF. 60.500 Morse sree x 58.000 BELUGA 138 (HZ) 60.500 peated +58.000 AMLP 230 (HZ) 60.500 ocr rrrrscre °58.000 SOLDOTNA 115 (HZ) 60.500 -------58.000 BRAOLEY 115 {HZ} 60.500 ------t SB.000 30.00024.00018.00012.0006.000027.000TUE,15.00021.000TIME9.00003.0000W4s47NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA,AMLP #1,NP #1 OFF. 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. EXISTING BRADLEY HYORAULICS W/30 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88E04.CHN TURBINE FLOW (CFS) 1600.0 reer ra *100.00 TURBINE HEAD (FT) 1200.0 ,cheneeieiaeteieiadelbd 900.00 NEEDLE OPENING (PU) 1.0000 ----0.0 PMECH (MW) 150.00 &a 0.0 t | { ' t =\_! \ 1 \ \ ' \ \ \ \ -\- T =30.00024.00018.00012.0006.00000.15.00021.00027.000TIME9.00003.000015:43NOV281989TUE,BRADLEYPARAMETERS® 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA,AMLP #1,NP #1 OFF. 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. FILE:WP88G04.CHN GOLO HILL 138 (HZ) 60.500 Moraes are x 58.000 BELUGA 138 (HZ) 60.500 aie +58.000 AMLP 230_(HZ) 60.500 Oo eennnnnene °58.000 SOLDOTNA 115 (HZ) 60.500 -----58.000 BRADLEY 115 (HZ) 60.500 --S"_--'58.000 ---_-10.0009.00006.00006.00004.00002.00000.07.0000TUE,5.0000TIME3.00001.000014:42NOV281989BUSFREQUENCIES 1988 WINTER PEAK.BERN 3 &4,SOLDOTNA, FILE:WP88GO4.CHN TURBINE FLOW (CFS) AMLP #1,NP #1 OFF. 25.7 MW BASE RATE CT SPIN,65.9 MW PEAK RATE CT SPIN. BRADLEY W/SURGE TANK &10 SECOND NEEDLE STROKE RATE. TRIP AMLP UNITS #6 &#7 CARRYING 111MW AT T =0.5 SECONDS. 1600.0 more +100.00 TURBINE HESO (FT) 1200.0 Orr errr renn °900.00 NEEDLE OPENING (PU) 1.0000 ---7 -t 0.0 PMECH (MW) 0.0 10.0009.00006.00006.00004.00002.00000.0TUE,5.00007.0000TIME3.00001.000016:06NOV281989BRADLEYPARAMETERS PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E FRI,DEC 01 1989 16:42 1988 WINTER PEAK.45MW TRANSFER @ UNIVERSITY INTO KENAI ARE BOTH BRADLEY UNITS ON-LINE.NO OTHER KENAI GENERATION. SRATOR SUMMARY: Is NAME BSVLT #MAC TYP MW 503 BRAD EQV13.8 1 2 43.0 691 TESORO1G24.9 1 +2 4.0 998 SOLD SVS 1 2 0.0 9985 UNIVRSTY 115 1 3 45.2 SUBSYSTEM TOTALS 92.2 MVAR QMAX QMIN VSCHED VACTUAL REM 0.3 39.3 739.3 1.0100 1.0100 1.9 1.9 -1.9 1.0100 0.9773 13.4 30.0 -25.0 1.0200 1.0200 9989 72.9 9999.0 -9999.0 1.0500 1.0500 12.7 10070.2-10065.2 MVABASE=10185.3 1988 WINTER PEAK.4SMW TRANSFER ©UNIVERSITY INTO KENAI ARE BOTH BRADLEY UNITS ON-LINE.NO OTHER KENAI GENERATION. BRADLEY W/90 SEC NEEDLE.REVISED OROOP &TIME CONSTANTS. ISOLATE KENAI UNDER 4SMW IMPORT CONDITION AT T =0.5 SECONDS FILE:WP88Q01X.CHN NET TURBINE HEAD (FT) 1200.0 Hor rcces cess x 900.00 TURBINE FLOW (CFS) 1600.0 acne +100.00 NEEDLE OPENING (PU} 1.0000 +-----------°0.0 PMECH (MW) 150.00 Tre Ts 0.0 BRADLEY 115 HZ) =ON id _- on Udoain«os &aoafooO uJo> .ud z -=©[om [aang fea! c=] o So o m =] oe to] x Nw fo] o Qo > Nw oe eo o u fo] io] Qo o S uda= Ue 7 o to] f=] " So So So So o f=) Qo °o °o o o oS o o nm 0.0 1988 WINTER PEAK.4SMW TRANSFER ©UNIVERSITY INTO KENAI ARE BOTH BRADLEY UNITS ON-LINE.NO OTHER KENAI GENERATION. BRADLEY W/30 SEC NEEDLE.REVISED DROOP &TIME CONSTANTS. ISOLATE KENAI UNDER 4SMW IMPORT CONDITION AT T =0.5 SECONDS FILE:WP88RO01X.CHN NET TURBINE HEAO IFT) 1200.0 Meee reneenae x 300.00 TURBINE FLOW (CFS) 1600.0 rT er +100.00 NEEDLE OPENING (PU) 1.0000 -----------°0.0 PMECH (MW) 150.00 --T era 0.0 BRADLEY 115 (HZ) 60.000 ee S0.000 30.00024.00018.00012.0006.00000.15.00021.00027.000MONTIME,19899.00003.000016:18DECO04BRADLEYPARAMETERS 1988 WINTER PEAK.4SMW TRANSFER ©UNIVERSITY INTO KENAI ARE BOTH BRADLEY UNITS ON-LINE.NO OTHER KENAI GENERATION. BRADLEY W/SURGE TANK &10 SEC NEEDLE. FILE:WP88S01X.CHN NET TURBINE HEAD (FT) REVISED DROOP &CONST. ISOLATE KENAI UNDER 4SMW [IMPORT CONDITION AT T =0.5 SECONDS 1200.0 Merc crrrecre x 900.00 TURBINE FLOW (CFS) 1600.0 rer OT +100.00 NEEDLE OPENING (PU) 1.0000 ----------=-°0.0 PMECH (MW) 150.00 ---7-7 7 0.0 BRAOLEY 115 (HZ) 50.000 --30.00024.00016.00012.0006.00000.015:1815.00021.00027.000MONTIMEf9.00003.0000DECO4%1989BRADLEYPARAMETERS