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HomeMy WebLinkAboutBPMC Meeting - March 5, 1991 2TO: FROM: DATE: SUBJECT: RECORD wOPy FILE NO Alaska Energy Authority —==: > 2/=—/a9 MEMORANDUM Bradley Lake Project Management Committee fi Brent N. petrie 2, 4/7 PEt) / Alternate Secretary, PMC —————— February 26, 1991 March 5, 1991 Meeting Enclosed for your review is a copy of the Draft Agenda for the March 5, 1991 meeting of the PMC. Please provide any corrections or additions to Chairman Kelly. The meeting place will be at Chugach Electric located at 5601 Minnesota Drive. The meeting will commence at 10:00 a.m. in the Training Room. Also enclosed for your review is a copy of the draft meeting minutes of the November 28, 1991 meeting, which will be considered at the next meeting. The executed September 21, 1990 meeting minutes for your records will be mailed under separate cover. DS/BNP/ds Enclosures as stated. Vv NU 12. we BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE MARCH 5, 1991 CHUGACH ELECTRIC ASSOCIATION TRAINING ROOM - 10:00 A.M. CALL TO ORDER 10:00 A.M. ROLL CALL PUBLIC COMMENT MODIFICATION OF AGENDA APPROVAL OF MINUTES November 28, 1990 TECHNICAL COORDINATING SUBCOMMITTEE REPORT INSURANCE SUBCOMMITTEE REPORT BUDGET SUBCOMMITTEE REPORT OPERATION AND DISPATCH SUBCOMMITTEE REPORT REVIEW OF PROJECT STATUS OLD BUSINESS a. Test Period Power NEW BUSINESS a. Approval of PMC Expenses b. FY92 Budget 1. CEA Dispatching 2 Adoption of Budget Schedule Next Meeting Date, Location, Time COMMUNICATIONS 4 ADJOURNMENT Kelly Burlingame Saxton Ritchey Sieczkowski Eberle Saxton Ritchey u DRAFT BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE NOVEMBER 28, 1990 CALLED TO ORDER Chairman Kelly called the Bradley Lake Project Management Committee to order at 11:07 a.m. in the Training Room at Chugach Electric Association to conduct the business of the Committee per the agenda and the public notice. ROLL CALL The roll call was taken and a quorum was established. In attendance were the following: , Alaska Energy Authority Robert E. LeResche - Representative Brent Petrie - Alternate Chugach Electric Association David L. Highers - Representative City of Seward E. Paul Diener - Representative Golden Valley Electric Association Michael Kelly - Representative Homer Electric Association N. L. Story, Representative Matanuska Electric Association Ken Ritchey - Representative Municipal mye and Power Tom Stahr - Representative John Cooley - Alternate Others Present: Stanley Sieczkowski - Alaska Energy Authority Dave Eberle - Alaska Energy Authority Ron Saxton - Purchasing Utilities DeAnna Scott - Alaska Energy Authority Joe Griffith - Chugach Electric Association Bob Hufman - AEG&T PUBLIC COMMENT Chairman Kelly introduced Mr. Hufman and welcomed him to the meeting. Chairman Kelly further asked if there were any members from the public present. There were none and Chairman Kelly proceeded to the next agenda item. Page 2 of 6 MODIFICATION OF AGENDA Under item 11, Old Business - Test Period Power was added as Item B. Under Item 12, New Business - Braking Resistor discussion was added as Item D. APPROVAL OF MINUTES September 21, 1990 Chairman Kelly asked if there were any objections to approving the September 21, 1990 meeting minutes as distributed. Chairman Kelly stated that there were a few grammatical errors and instead of going through each one, would hand the copy to Ms. Scott to make proper corrections. Mr. Ritchey motioned, Mr. Diener seconded that the September 21, 1990 meeting minutes be approved as corrected. The roll was called and the motion passed unanimously. TECHNICAL COORDINATING SUBCOMMITTEE REPORT Mr. Burlingame reported that the Technical Coordinating Subcommittee (TCS) met twice since the last PMC meeting. Mr. Burlingame reported that the TCS has accepted the recommendation of SWEC to delete the installation of the braking resistor at Bradley Lake. The TCS has accepted the recommendation of SWEC to install digital stabilizers on the Bradley Lake units as opposed to the analog stabilizer. Studies were conducted and revealed the two are not equal. The digital stabilizers will provide a better performance. Mr. Burlingame also reported that the TCS has accepted the recommendation made by SWEC to install one SVS at the Daves Creek northern side and the other in Soldotna. The committee also approved that an alternative bid use Thyristor Switched Capacitors at Soldotna. This would allow use of a smaller reactor transformer. The TCS has deleted certain costs from the SWEC contract related to converting the machine test data into IEEE format and recommends that the ASCC acquire the PTI Software. Mr. Burlingame stated that the TCS will be reviewing how the project should be operated under different scenarios and defining certain operating constraints. INSURANCE SUBCOMMITTEE REPORT Mr. Saxton reported that the Energy Authority received property insurance premium quotes from the Division of Risk Management. Mr. Saxton stated that the estimates came in low compared to the Four Dam Pool Insurance. For the greatest level of insurance coverage, the premium would be $215,000. The Insurance Subcommittee will be meeting in a couple of weeks to address this. Mr. Saxton stated that the Division of Risk Management will solicit actual quotes to place insurance on the Bradley project. Mr. Saxton further stated that the transmission lines are not covered and that they would be "insured" through the Renewal and Contingency fund. Mr. Saxton added that the insurance estimate the Budget Subcommittee had used was $375,000. 8. 10. Page 3 of 6 BUDGET SUBCOMMITTEE REPORT A. AEA Administrative and General Costs Mr. Ritchey reported that the Budget Subcommittee met at 8:30 a.m. on November 28, 1990. The main item discussed at the meeting was the Administrative and General (A&G) Costs of the Energy Authority. The subcommittee was directed by the PMC at the last meeting to come back to the PMC with an agreement between AEA and the PMC on the A&G costs somewhere in the area of $200,000 with some sort of a cap. It was decided in the subcommittee meeting that AEA would receive $250,000 for the FY92 A&G cost instead of $265,000. As far as a cap, none was decided. However, it was agreed upon by the Budget Subcommittee that each year this would be reviewed. Mr. Ritchey further stated that the Fiscal Year budget will need to be approved no later than April 1, 1991. Mr. Ritchey asked direction from the PMC on how this information is to be presented. Mr. Ritchey suggested: 1) it could be in the form of a presentation or 2) the Budget Subcommittee can distribute the budget report to the Managers and at the next PMC meeting it can be approved or disapproved. Mr. LeResche suggested that each principal should review the Budget material prior to the next meeting. It was also noted that if there were questions on the budget each member could address them with their representative on the Budget Subcommittee. Mr. Ritchey stated the only other change to the Budget was the Property Insurance for Bradley. BE CEA Dispatching Costs This will be addressed at the Budget Subcommittee meeting in December. C. CEA and HEA Wheeling Costs This will be addressed at the Budget Subcommittee meeting in December. Mr. Ritchey stated also the subcommittee will look at the HEA O&M Cost and whether the Bradley Lake Trustee would be the central point to pay. Mr. LeResche stated that net billing of O&M costs through Bradley Lake debt service cannot be allowed. HEA’s wheeling costs would have to be dealt with directly on the utility level. OPERATING AND DISPATCH SUBCOMMITTEE REPORT Chairman Kelly introduced Mr. Sieczkowski as the new Director of Facilities Operation and Engineering at the Alaska Energy Authority. Chairman Kelly asked the PMC if there was any objection to appointing Mr. Sieczkowski as Chairman of the Operation and Dispatch Subcommittee. There was no objection from the PMC and Mr. Sieczkowski was appointed. REVIEW OF PROJECT STATUS Mr. Eberle reported that the project is now 87% complete. The diversion gates at the dam were closed October 31, 1991 for start of the reservoir fill. The reservoir has risen only six inches due to extremely cold temperatures. The streams have frozen over and most of the water entering the reservoir is being released for the 40 cfs minimum fisheries flows. The lower power tunnel concrete liner has been completed and grouting 11. Page 4 of 6 is now three-fourths complete. The powerhouse generators and major components are now in place. The substation and transformers are complete and are being tested. Hook up to HEA at Bradley Junction is scheduled for January 15, 1991. The transmission line has been completed and the contractor is finishing work on the punch list items. Mr. Eberle stated that everything is on schedule and the commercial operation date is still set for September 1, 1991. Mr. LeResche asked when the site restoration contract would go out for bids. Mr. Eberle responded that it will be issued in January 1991 and will be awarded in April or May 1991. Mr. Saxton questioned whether the site restoration cost would be over or under the amount that has been set aside. Mr. Eberle responded that it likely will be under the dollar amount allowed. Mr. Eberle further stated that the only outstanding contract after the site restoration contract would be the SVS contract. This RFP will be released in January 1991 and the contract awarded in May or June 1991. OLD BUSINESS A. Start-up Test Protocol Document Mr. Eberle distributed to the PMC a copy of the Test & Start-Up Program that will be used for the Bradley Lake project and the Start-up Sequence. Mr. Eberle stated that this information was distributed at the Technical Coordination Subcommittee meetings. The spinning of the units (dry) will take place at the end of April. The tunnel will be watered up and tested in early May. Both units will be on line for testing in June/July with load testing after the first synchronization. Mr. Eberle stated that the dispatchers would need to get involved in this portion of the start-up and testing. SWEC has established a milestone date of August 1, 1991 to complete testing. This is not to be confused with the commercial operation date of September 1, 1991. Mr. Eberle reported that a start-up coordination group will need to be organized in May. At that time, we will be inquiring as to any black out dates for each utility. Mr. LeResche asked Mr. Eberle to discuss how construction crews are giving over completed items to Operations. Mr. Eberle stated that after a construction item has been completed, the item is tested by the contractor. After the contractor has completed its testing, AEA then tests the item a second time before the item is accepted. After AEA has accepted the item, AEA operation personnel hang their tags on the equipment and assume operational control of the item. B. Test Period Power Chairman Kelly stated that according to the September 21, 1990 meeting minutes there was discussion of test period power, and that a group was created to address this. Chairman Kelly asked if a meeting or teleconference had taken place to address this. Mr. Saxton replied no. Chairman Kelly asked Mr. Highers if he would look into the power cost adjustment with APUC. Mr. Highers concurred. Mr. Stahr stressed his concern with the fluctuation of the cost between the "test" period and the commercial operation period. 12. Page 5 of 6 NEW BUSINESS A. Amendment No. 1 of the Intertie Operating Committee Agreement Mr. Saxton reported that REA has accepted the language of the Amendment No. 1 of the Intertie Operating Committee Agreement. What is now needed is to have each utility governing body approve the amendment. This action is needed to amend the insurance clause and it will need to be sent to REA. This allows the Municipal Utilities and the State to self-insure and not the Co-ops. Chairman Kelly requested that each member receive an original document to be addressed by the Board of Directors of each utility. Approval of PMC Expenses Mr. Saxton distributed to the PMC a copy of the schedule of Unreimbursed Bradley Lake Costs - As Submitted to Ater Wynne November, 1990. The following costs are identified: PROJECT COSTS ML&P - Finance Team Activities $ 1,976.76 New York Trip Ater Wynne- BPMC Legal and Finance Costs Associated with Closing 12,965.38 Chugach 1990 Utility Opinion Letter 2,318.30 GVEA TCC Expenses 1,181.69 HEA TCC Expenses 910.84 TOTAL $19,352.47 Mr. LeResche motioned, seconded by Mr. Story that the Project Costs totaling $19,352.46 be approved for reimbursement. The roll was call and the motion passed unanimously. Mr. Saxton stated that Ms. Rawitscher of AEA has not looked at these submittals and if any adjustments are needed, they will be made at a later date. Mr. Saxton further stated that, in addition, the following Section 31 costs are associated with the Bradley Lake Project Management Committee. The following costs were identified as: SECTION 31 TS - Bradley Organization GVEA $ 6,504.87 HEA 915.41 Ater Wynne 1 14 TOTAL $26,274.42 Mr. LeResche motioned, seconded by Mr. Diener to approve the Section 31 Cost as reported. The roll was called and the motion passed unanimously. Page 6 of 6 C. Approval of HEA Bradley Junction Cost Mr. LeResche stated that the Technical Coordinating Subcommittee had previously discussed and recommended that HEA install the dead-end, switchin structure at Bradley Junction. This was addressed several times at the TC. meeting and it was agreed that HEA could best accomplish this job. Mr. LeResche motion, seconded by Mr. Diener that the work completed by HEA for the installation of the dead-end switching structure at Bradley Junction be approved as a project cost and that reimbursement be made to HEA. The roll was called and the motion passed unanimously. D. TCS - Braking Resistors (Continued Discussion) Mr. Stahr asked if funds allocated for the braking resistors could be set aside for other uses. He stressed that he would prefer to have the braking resistors sitting at the project or have the funds already set aside if the braking resistors are needed. Chalnman Kelly asked if this could be added to the project budget if it is determined that the braking resistors are needed at a later date. Mr. Eberle stated that the cost of the braking resistors are part of the overall project budget, and there is no need to set these funds aside at this time. Mr. Eberle stated the project budget will not be closed out until the SVS’s are in place. Mr. LeResche stated that the remainder of the construction funds are in the hands of the trustees and all of the project money will be there until the project is closed. After a long discussion Mr. Stahr_moved, seconded by Mr. Story that the PMC approve the deletion of the braking resistors with the provision the PMC reserves the right to recommend installation prior to the close out of the project. The roll was Called and the motion passed unanimously. = SCHEDULE NEXT MEETING March 5, 1991 Chugach Electric Association Training Room 10:00 a.m. ADJOURNMENT There being no further business before the Committee, the Committee adjourned by acclamation at 1:15 p.m. Chairman Kelly ATTEST: Secretary Approved by PMC at meeting held February 22, 1991. CHUGACH ELECTRIC ASSOCIATION, INC. Anchorage, Alaska November 26, 1990 TO: Bradley Lake Project Management Committee FROM: David Burlingame, Technical Coordinating SubCommittee Representative SUBJECT: TCS Meeting of October 25, 1990; November 16, 1990 Below is a synopsis of the last two TCS meetings: Braking Resistor Application The TCS has accepted the recommendation of SWEC to delete the installation of the braking resistor at Bradley Lake. The recommendation was based on several considerations. The main considerations are as follows: - The frequency excursion above 61.5 Hz only occurs in one dispatching scenario with summer loads and Bradley Lake at 120 MW and Cooper Lake at 16 MW without any other generation resources. - The original reason for proposing the use of the braking resistor was to eliminate unit tripping of one Bradley Lake unit for faults between Bradley Lake and Soldotna. The governor manufacturer has indicated the modifications assumed possible with the application of the braking resistor are not technically possible. Unit tripping will be required for faults between Bradley Lake and Soldotna. - The control problems associated with the braking resistors require blocking of the Automatic Generation Control (AGC) during the event. This keeps the frequency well above 60.0 Hz longer than not using the braking resistors. With braking resistors, the frequency rise is kept below 61.5 Hz but the frequency decays much slower and is still at 60.8 Hz 10 seconds after the fault. Without braking resistors and ignoring AGC, frequency rises to 62.6 Hz but returns to 60.8 Hz in approximately 5 seconds. Tripping of the Cooper Lake units would limit the overfrequency to 62.3 Hz. The frequency excursion is out of the set criteria for approximately 2.5 seconds. Consideration of AGC would not reduce the maximum frequency rise of 62.6 Hz, but would contribute to a more rapid return to 60 Hz. DIGITAL STABILIZERS The TCS accepted SWEC's recommendation to install digital stabilizers on the Bradley Lake units as opposed to analog. Digital stabilizers were originally proposed by PTI but SWEC recently recommended they be replaced with the less expensive analog stabilizers based on equal performance between the two types. Further studies revealed the two types not equal, with digital stabilizers providing the better performance. SVS SYSTEMS The TCS accepted SWEC's recommendation to install one SVS at Daves Creek and one SVS at Soldotna. This recommendation included several items: second intertie. If it were built to survive the loss of the new intertie without unit tripping, the size of the SVS would more than double. Studies indicate that if desired, any SVS associated with the new intertie should be further north. 4 - The SVS at Daves Creek will not be sized to accommodate new ( tl - SWEC must insure the startup and other technical requirements included in the specification are also met. - The committee approved the alternative use of Thyristor Switched Capacitors (TSC) at Soldotna. This will allow an alternative bid on the SVS using smaller reactors transformers with improved startup performance. - The SVS size at Soldotna will be verified by SWEC to insure there are no voltages above 115%. PTI SOFTWARE The TCS deleted certain costs from the SWEC contract related to converting the machine test data into IEEE format and recommended the ASCC acquire the PTI software. This recommendation was based on the difficulty the utilities are having with Electrocon committing to update their program to include the IEEE models and the utilities' desires to utilize the $280,000 worth of machine data gathered after the Bradley Lake project is completed. INTERIM OPERATING LIMITS The TCS received a verbal report on the expected operating constraints for Bradley Lake prior to the installation of the SVS systems. Basically, without a gas fired turbine on the Kenai, the Bradley Lake power output must roughly equal the amount of load on the. Kenai. In the summer Bradley's maximum power output without gas-fired generation is 55 MW, with approximately 16 MW being exported from Daves Creek. With gas fired generation on the Kenai, Bradley can be raised to 80 MW, with 70 MW available for export from Daves Creek. In the winter, Bradley's output is restricted to 65 MW, with only 2 MW available for export from Daves Creek. With a gas-fired turbine on the Kenai, Bradley can be raised to 80 MW, with 25 MW available for export from Daves Creek. The TCS briefly discussed how the plant could be tested to insure it is capable of delivering 90 MW. This will be addressed later in the start up and testing plan. [Ema BRADLEY LAKE PROJECT TEST & START-UP PROGRAM BACKGROUND In June 1986, Stone & Webster Engineering Corporation (SWEC) presented the then Alaska Power Authority, now Alaska Energy Authority (AEA), with suggestions and recommendations regarding the plant start-up and acceptance tests for the Bradley Lake Project. The multiple phase program which was recommended for Bradley Lake, was based on SWEC’s involvement in numerous hydroelectric projects over the past 30 years. The test and start-up program phases were developed as a result of the experiences learned from the start-up of earlier plants. Previously, plant start- ups were often accomplished by trial and error and performed by the constructor with little or no involvement by the engineers. Unfortunately, numerous delays were experienced in achieving commercial operation due to equipment damage or misoperation during this trial and error period. The multi-phase test program was instituted resulting in improved plant operation and a safe and reliable plant performance. This test and start-up program has been refined over the years incorporating new and proven methods of demonstrating that plant equipment and systems have been tested, functionally checked out, safely operated and are ready for commercial operation prior to turnover of the equipment or system to the plant operating staff. The test and start-up program developed for the Bradley Lake Project, is very similar to that utilized and proven at other hydroelectric projects such as the Raystown Hydroelectric Project, William F. Matson Generating Station in Huntingdon, Pennsylvania. This project was designed, tested and started up by SWEC personnel and began producing power in November 1988. During the first fiscal year of operation (November 1988 to October 31, 1989), plant availability was 97 percent. This proven program is being implemented at the Bradley Lake Project. START-UP PROGRAM MANUAL The Start-up Program Manual which has been developed for the project includes four volumes: I) Administrative Procedures, IT) Generic Test Procedures, III) Pre- Operational Test Procedures and IV) Start-up Test Procedures. ADMINISTRATIVE PROCEDURES The Administrative Procedures is comprised of four subsections. They are Start- up Program, Start-up Safety Tagging, System Boundary Identification and System Turnover Dates. The start-up program defines the phases of the test and start-up program, identifies the various participants involved in the program and outlines their duties and responsibilities. The organization for this test and start-up program is shown on Attachment 12.3. D. The Start-up Safety Tagging Procedure establishes a policy for the isolation and tagout of power plant equipment in order to assure safe working conditions for all personnel at the plant site and to prevent damage to equipment. The System Boundary Identification Procedure illustrates a breakdown of all project systems so that the contractor can identify and plan his work to ensure that a complete system will be turned over for Preoperational Testing. Applicable design drawings, such as One Line Diagrams and P&ID’s, are included as part of the procedure with system turnover number designations for each system shown in the circled portion of each drawing so that the contractor will know what is required for each system turnover. The final Administrative Procedure is System Turnover Dates. This procedure identifies each system and the date required for that system to be turned over to the Contractor’s Start-up Group for construction testing. TEST AND START-UP PROGRAM PHASES There are three phases of the Test and Start-up Program, as shown on Attachment 12.1. These are: 1) Construction Testing Phase, 2) Preoperational Testing Phase and 3) Start-up Testing Phase. 1. Construction Testing Phase This first phase defines the Contractor’s responsibility for performance of construction tests for both contractor supplied equipment and owner supplied equipment. A series of Generic Test Procedures have been provided as Volume II of the Start-up Program Manual for the Contractor’s use for testing of equipment and systems during the installation process. These generic procedures require electrical, mechanical and instrumentation verification for such things as meggering, circuit checkout, motor rotation checks, system inspection, system flushing, instrument device calibration and instrument loop calibration. Data sheets are included in the procedures to record results of such testing and provide baseline data for later use when the maintenance of this equipment is performed by the plant staff. An example of a generic mechanical test procedure is MTP-6, Initial Operation of Rotating Equipment. This procedure outlines the prerequisites to be completed before attempting to operate a piece of equipment such as ensuring that proper lubrication has been performed, that the alignment is correct and that personnel performing the test are familiar with the equipment and knows it’s limitations. Instruments to measure temperatures, vibration and current are to be operational and onhand for use during the initial start. System valve alignment and electrical power requirements are defined and applicable tagging to ensure a limited or complete flow path and safe operation are also defined. The results of the initial run are recorded on the applicable data sheets which are part of the procedure ETP-3, Controi Circuitry Checkout, is an exampie of a generic electrical test procedure. The purpose of this procedure is to determine by functional testing that each electrical control circuit operates, interlocks, controls, indicates and alarms in accordance with the latest approved elementary, logic and wiring diagrams. This is done by isolating the power source to the motor, energizing the control circuit and initiating each device in the control circuit to functionally prove that the circuit operates as designed. The applicable diagram is red lined as the functional testing is performed and is included in the turnover package. Proper tagging procedures and other safety measures are utilized during the performance of this testing. Generic instrumentation procedures are also included. ITP-2, Instrumentation and Controls Installation Checkout verifies that instruments and associated piping, mounts, racks and accessories are installed according to the latest approved installation drawings and that the installation conforms to good construction practice. A visual inspection of all instrumentation and associated piping and wiring is performed and documented. The performer also verifies that the instrument pneumatic piping has been blown down and leak tested and that all wiring terminations are correct as shown on the latest wiring diagrams. 2. Preoperational Testing Phase The Preoperational Testing phase, which is the second phase, follows the Construction Testing Phase and is the responsibility of the Contractor’s Start-up Group for contractor supplied equipment and the SWEC Start-up Group for owner supplied equipment. These Preoperational Test Procedures are contained in Volume III of the Start-up Program Manual and provide all tests and checks which are necessary to insure that each mechanical/electrical/hydrocivil system is functional before start-up testing of the overall integrated plant commences. The purpose of these procedures is to verify that each system performs in accordance with design requirements. This is accomplished as outlined in a step by step operation of the system and witnessed and approved by SWEC, Bechtel, the Owner’s authorized representative and the Contractor or equipment manufacturer's representative, as applicable. The Preoperational Test Procedures are listed under Section 1 - General Civil Contract, Section 2 - Powerhouse Contract, Section 3 - Transmission Line Contract and Section 4 - Owner Furnished Equipment. As an example of a typical General Civil Contract, Preoperational Test Procedure, PTP-1-2 Power Tunnel Gate Shaft Sump Pump System describes the method of testing this system to demonstrate that it will operate in all design modes of operation and that the system meets capacity requirements. For instance, step 6.1.4 states "From a local water supply, using a hose with shutoff valve, fill the sump with water and verify/perform the following: 6.1.4.1 Pump ODFM-P3 starts in AUTO from level switch when water level reaches approximately 18 inches." There is a si__ »ff section for the performer andw _sser and a date. This confirms that under normal plant operating conditions that in the event of excess water in this sump, that the pump will start automatically and discharge the water from the sump. All other design parameters for this sump pump are also tested in a similar fashion. Another example of a typical Powerhouse Contract, Preoperational Test Procedure is PTP-2-13A Powerhouse Fire Protection - Water, which describes the method of testing this system in a step by step test of each design mode. Step 6.1.6 of this procedure states the following: "While observing the pressure on OFPW-17, gradually OPEN bypass valve OFPW- V6 and verify that OFPW-PS7 actuates at 125 PSIG and alarm A-041-2 FIRE PROTECTION TROUBLE annunciates.” The performer and witnesser sign off and date the event acknowledging that this step was acceptable in the performance of the procedure. Similar detailed performance tests are required for each system within the powerhouse, gate houses, etc. A complete listing of the various systems is contained in Volume III, Books 1, 2, and 3 of the Start-up Program Manual. Upon completion of each preoperational testing phase, the proper operation of each individual system will have been verified and all systems and equipment will be ready for integrate plant testing. As part of the preoperational testing and as “hands on” training, the Owner's operators will operate the equipment/system for both SWEC and the Contractor throughout this phase of testing. 3. Start-up Testing Phase The third and final phase is the Start-up Testing Phase of the overall plant integrating all systems and equipment. This phase will be accomplished by the SWEC Test Engineers in coordination with Bechtel, the Owner’s Start-up Representative and those Vendor's representatives necessary to ensure satisfactory operation of the entire plant and all supporting equipment. Start-up Test Procedures are contained in Volume IV of the Start-up Program Manual and outline tests to be performed on the turbine-generator, governor and controls, voltage regulator and excitation systems, relays and protection equipment and the SCADA system to verify integrated operation. A typical powering up of the plant could begin by energizing the 115 kv transmission line and backfeeding into the Bradley Lake substation where trip tests of transmission line breakers are performed in conjunction with the utility company representatives who control the other end of the transmission lines. These tests will be coordinated by the SWEC Test Engineers and Owner’s Start-up Representative in harmony with the utility representatives. Upon satisfactory completion of these tests, the main transformers will be energized with the generator breakers locked open to prevent backfeeding the generators. The 480 V station service switchgear and the 12.47 kv permanent facilities feeders will be energized next and subsequently the 480 v motor control centers. F. The next m _— event is watering up of the intak id power tunnel. This will be performed i. a.cordance with STP-3 after a final ...,ection of the tunnel and upon successful preoperational testing of the power tunnel bulkhead gates, Unit 1 and 2 spherical valves, powerhouse drainage system and Unit 1 and 2 turbine generators and supporting systems. The unit first rotation is performed next followed by turbine overspeed testing, synchronizing checks for each generator to the transmission line system, and on line performance tests. All of these events are covered by detailed Start-up Test Procedures (STPs). For example, STP-11, Unit Load Rejection Test Procedures, will outline the steps taken to perform these tests which are normally performed at 25%, 50%, 75% and 100% of the full load capacity of each unit. The usual practice is to trip the main generator breaker at each of these levels which simulates a possible trip at each of these levels during normal plant operation. The purpose of these tests is to prove that the turbine generator and associated equipment and systems will react properly and safely shut the unit down as designed. These tests are coordinated with the Load Dispatcher to ensure that system generating capacity is available to pick up the load at the time that the Bradley Lake unit is tripped off line. SCHEDULE OF TESTING Construction and preoperational testing has begun on some minor plant equipment and systems; however, the majority of construction testing should begin in September 1990 followed by preoperational testing in mid fall of 1990. The start-up testing effort will begin in October 1990 for the SCADA system and will continue to plant commissioning scheduled for September 1, 1990. PLANT TURNOVER Upon successful completion of all three phases of start-up testing for each turbine generator and combined operation of both units, and when all punchlist items or deficiencies have been completed, SWEC will prepare a final Turnover Package with the results of the start-up testing for review and approval. The plant will be released to the Owner for operation. When (SWEC) verifies and determines that all testing has been successfully completed, that the design has been proven and that the plant is ready for commercial operation. The System Turnover Sequence is as illustrated on Attachment 12.2. G. SUMMARY The Test & Start-up Program for the Bradley Lake Project is a detailed, reasonable and proven program. This multi-phased program surpasses the industry norm for plant start-ups and upon its successful completion will ensure the owner that the plant is ready for commercial operation. The Raystown Project power production exceeded all expectations of Allegheny Electric Cooperative, Inc. and has an outstanding record of reliability and availability. The Bradley Lake Project should be capable of attaining similar levels of reliability and availability due to the extensive test program being conducted at the project site. Gsces iin BRADLEY LAKE PROJECT SYSTEM CHECKOUT & STARTUP SEQUENCE i-d¥ ANSWHOVLLY CONTRACTOR SUPPLIED EQLUPMENT PREOPE FH [a 4 ATs c a TESTING PHASE PHASE NOTES: CONTRACTORS: 1. ETP.S - ELECTRICAL TEST STARTUP PROCEDURES Group 2. MIP'S - MECHANICAL TEST PROCEDURES 3. 11P'S - INSTRUMENT TEST EIPS Saad, OPERA RON PROCEDURES “TMEGGERING ” OF EQUIPMENT 4. FIPS - PREOPERATIONAL ~ CIRCUIT CHECKOUT - INITIAL OPERATION JEST ERO CEOS - MOTOR ROTATION CX OF SYSTEMS oe “MIPS - SYSTEM FLUSHING - SYSTEM INSPECTION . - SYSTEM FLUSHING - VERIFICATION OF SYSTEM “HPS.08c) OPERATION CONDITIONAL - INST. DEVICE CAL. SYSIEM IO - INST. LOOPCAL. TOOWNER OWNER SUPPLIED EQUIPMENT ae OPERATIONAL SWEC JSURSIDICTION a STARTUP GROUP SWEC STARTUP GROUP OWNER OPERATES GECHTEL | - °SIeS (FINAL TURNOVER) ry POWER oem OPERATION ee UNIT TO PRODUCE SYSTEM | - UTIL OPERATION OPERATION OVER OF SYSTEMS - TURBINE GENERATOR TOSWEC | - SYSTEM FLUSHING UNIT TESTING STARTUP | .pTPS - ON LINE UNIT TESTING - VERIFICATION OF SYSTEM ~ COORDINATED UNIT OPERATION TESTING OPERATOR'S SYSTEM OWNERS OPERATORS AVARABLE TO OPERATE ese OWNERS OPERATORS OPERATES SYSTEM FAMILIARIZATION FOR PREOPERATIONAL AC TIVITIES FOR BOTH SWEC AND CONTRACTORS UNDER SWEC STARTUP GROUP'S DIRECTION up 5-22 BRADLEY LAKE PROJECT SYSTEM TURNOVER SEQUENCE nermameranen ln ELECTRICAL ec aTMCTOR eSNTRASTOR CONTRAGTOA CONTRACTOR wae ie COMPLETES WORK COMPLETES WOF CONTRACTOR SUPV eae a CONTRACTOR SUPV} | CONTRACTOR SUPV] | CONTRACTOR SU VENONS VERIFIES VERIFIES VERIFIES WORK COM WORK COMPLETED WORK COMPLETED WORK COMPLETED | | WORK COMPLETED WORK COMPLETE INITIATES SYSTEM TO TO SWEC STARTUP 3 ti B AP-1 ATTACHMENT M1188078 2 Lo armenens 71.3 Comunications 33.6 SCA, AnD 27-0 Puce RS 278 rus 6 Oo 27.1 Mas erase cates | 27.10 seienic nouitors | hy AIM TAM Tit eRe APART) UNET 1 19.0nv 20.6 oATeswrT ane 20.9 GATESWFT WAC €.2UG erm Pees 7.4 71m Breage Hb Pussy one 2.1 arn evo 20.1 1104 Press GATES 20.2 O1vension tee. 22.2 @riuavay Rove, Be ln MBSE pee leas, sages HEP STARTUP SEQUENCE BRADLEY LAKE HYDROELECTRIC PROJECT ALASKA ENERGY AUTHORITY BEER CHEBRIBS ENGINEERING CORP ___J.0, No. 15808,53 A REVISION 1|-87?790 eee seer ee ene Fe i ac (UR SEP TORT Tey Ter PE ee Pe ny 1) | TR SEP RY Tf TP Ye . pooo20ooc00000 [. wee ff*s°" ALASKA ENERGY AUTHORITY BRADLEY LAKE HYDROELEC POWER PROJECT START-UP SCHEDULE Lees een en nee ee eee eae Re) (UT SEP OCT (ety Ter 1 JAN FER Re Pe Ay 0 TA TP SEP | OY Ty Te RY Te | ALASKA ENERGY AUTHORITY BRADLEY LAKE HYDROELEC POWER PROJECT START-UP SCHEDULE STP-3 STP-2 STP-34,B STP-4 STP-5 STP-6A,B STP-7A,B STP-8A,B STP-9A,B STP-104,B STARTUP PROCEDURE OUTLINE Reservoir Filling: Controle filling of the reservoir, leak teating of power tunnel gates, inspections and monitoring during filling, and reporting procedures. Tunnel Filling: Contrele filling cf the tunnel and wonitoring of tunnel during and after filling. Tunnel will be initially filled with one spherical valve open, thus filling one unit spiral case at the sane tine. The other unit spherical valve will be closed. Unit 1¢2) Water-Up: Filling of unit spiral oase for unit with a closed spherical velve and the tunnel filled, or if a unit spiral case ie unwatered. 115kVY Transmission Lines and Substation Energization: Energizes lines and 115kV substetion. Verifies phasing of conductors and VTs. Plant Energization: Energizes the main power transformers, and the main 15kV bus. Verifies phasing of conductors and VTs. Unit 1(2) First Rotation: First rotation of the turbine-generator. Bearing run-in, shaft run out, and initial balancing are included. Unit 1(2) Overspeed Trip Test: Speed switch test of electronic, mechanical-electric, and nechanical- hydraulic speed switches. Unit 1(2) Generator and Exciter Tests: Temporary excitetion from the 15k¥ bus is provided and open ofrouit saturation, TIF, waveform, and short circuit gaturation tests are run. The excitation is then oonnected normally. Unit 1¢2) Initial Synchronizing: Verification of ganual and automatic synchronizing. First synchronising of the units to the systen. Adjustnents of the exciter, voltage regulator, and power systen stabilizer. Unit 142) Automatio Control and Trip: Online demonstration of the autonatio start, and normal stop cirouits. This test will be used for operator training for normal unit operation. Funotional tests of protective relay circuits sre performed. STP-11A,B STP-124,B STF-134,3 STP-14 STP-15 Unit 1(2) Remote Operation: Online demonstration of the renote (CEA dispatcher) operation of the unit. Includes governor mode changecvers, verification of dispatch RTU (RTUZ) I/0, and substation control. Unit 1(2) Load Runs and Rejecticn: Load operation at 25%, 50%, 75%, and 100% of load. Searing, oil, and stator tenperatures will be verified. Operation and parameters of cooling systems evaluated. After the run at each load step, the lead will be rejected for the load rejection evaluation. The maximum load may be restricted by system configuration at the time of test. Unit 1¢2) Acceptance Test: Vibration, final balance, governor control and stability, and unit efficiency tests will be perforned on both units. One generator will heave; generator heat runs, zero power factor saturation test, generator efficiency tests, and a sudden short circuit teat run. The same tests nay be perforned on the other unit depending on the resuits of the first unit tests. Power Station Acceptance Test: Combined performance tests of the station. Two unit in parallel stability and governor oontrol, dispatch control and node changes, and two unit load rejections are included. SCADA Syeten Availability Guarantee Test: Six sonth operation cf the SCADA systen to demonstrate guaranteed reliability. tH URE (NBURSED BRADLEY (KE COSTS COSTS INCURRED AS Submitted to Ater Wynne Wovesber, 1990 PROJECT COSTS | cmonce' | cea? | wget I wer? | A | mut | scuneo | ams me? | om | 2 | ai Noe ' FINANCE TEAK | | | | 1,976, % : 17K al ACTIVITIES 0.00 8.00 0.00 | 0.00 | 0.08 | 0-00- | 0.00 0.00 | 0.09 | cone ae | | Oo | 12S $ ed jrrmace OOF 0.00 0.00 | 0.00 0.08 0.00 | Pree | 0.00 12,965.38 | 44,9¢1-64-| { \s ack | | [1990 UTILITY | | lopruion Letters | 2,318.30 | 0.00 0.00 0.00 0.00 0.30 0.00 0.00 | 2,318.30 | | a5 » | | | Tec One ! | | | | EXPENSES 0.00 | 1,181.69 0.00 10.86 | 0.00 0.00 0.09 | 2,092.53 | | Tt 7 | TOTAL 2,318.30 | 1,181.69 0.00 910.84 | 0.00 | 1,976.26 | 0.00 [ 12,965.38 19,352.47 wl — 4 ? S2(a)> BPRC ORGANIZATION G.00 &, 504.87 0.00 915.41 0.00 { Q.c0 0.00 7,420.28 | s82¢b) BPHC LEGAL 0.00 0.00 6.00 soe “-- 0.00 9.00 16,854.14 18,854.14 | 3 Ty TOTAL | 0.00 6,504.87 | 0.00 | 915.46 0.00 0.00 | 0.00 18, 854.14 1 26,274.42 t el i: Lt =k : a Loyes 1. Data submitted to Ater Wynne via letter dated November 15, 1990 from Carol Johnson, Chugach. 2. Unreimbursed Bradley Lake Costs Forms submitted to Ater Wynne November 7, 1990. 3. Unvrei mbursed Bradiey Lake Costs Forms submitted to Ater Wynne, inc luded costs for July, August, Septesber andi October, 1990, not previously submi ttect. 4. Expenses for the Bradley Lake Borad Closing were sutmitted via letter dated November 15, 1990 from Iom Stashr, ML&P. 5. Includes legal fees and expenses from August, September, October, 1990. EGW\eqw082R .WOZ QCAUGALH ELEUI KIC \ ASSOC ON, INC. a November 15, 1990 VIA _FAZ Ronald L. Saxton Ater Wynne Hewitt Dodson & Skerritt 222 S.W. Columbia, Suite 1800 Portland, OR 97201-6618 Dear Ron: In response to your October 30 memo to the Bradley Lake Utility Managers, Chugach has incurred $2318.30 in legal expenses related to preparation of the opinion letter in addition to the $4116.00 in David Higher's August 21, 1990 letter to you in this regard, a copy of which is enclosed. Very truly, yours, Carol Johnson General Counsel Enclosure ce: David L. Highers 111890\CJ*ron\amh 5601 Minnesota Dive © RO. Box 196300 © Anchorage, Alaska 99519 6300 F one 907-563-7494 ¢ FAX 907-562-0027 Anchorage, S& FIZ y~VveUr UN IMBURSED BRADLEY wAKE COSTS UTILITY GVER MONTH June 1990 RETURN NO LATER THAN PROJECT COSTS al 1990 FINANCE TEAM PARTICIPATION All travel-related expenses for mmnbere of the Piasase foam fer tripe and meetiags asoeciatad with the eenend financing. LEGAL EXPENSES POR FINANCING EFFORTS Leeel fees of the Committees ettaruey Telating te tue couend {isancing etfert. Saxtos will previde OPINIONS OF COUNSEL Sewps of work on 1990 sessed fisenciag effort te be duterniagt later. Gene satil requested TCC EXPENSES Prevel and ascting expenses asceciatad with your atility’s participation ca the feekaisal Coerdisatiag Committas. Op ust izeleds aneuntes fer staff tins. SECTION 31 COSTS $1,720.01 (3) Lage, qupmnses fag representation of Camitres. 8,058.78 PREPARED BY APPROVED BY authori tink ,, Mart et. al. Alesis Beery « 222 ow Columbia, Sta. 1000 ie Anaherege, Alaska 1 -0869 Kh oind, OR 97303 UNREIMBURSED BRADLEY LAKE COSTS UTILITY GVEA MONTH JULY 1990 RETURN NO LATER THAN PROJECT COSTS CATEGORY TOTAL AMOUNT al 1990 FINANCE TEAM PARTICIPATION All travel-related expenses for members of the Pinsace Seam for tripe and meetings associated with the gecond financing. A2 1990 LEGAL EXPENSES FOR FINANCING EFFORTS carga fews vi tus Quameittece atterney Samten will provide relating ts the second financing to ARA effort. a3 1990 OPINIONS OF COUNSEL Seope of work on 1990 second financing Mone until requested effort to be determined later. by ABA aS 1990 TCC EXPENSES Travel and meeting expenses aseociated with your utility's participation on $554.00 the Technical Coordinating Committee. bo not include amounts for staff tine. SECTION 31 COSTS (8) 89WE-appreved costs for conducting Cummittee meetings snd general business. 1,422.92 Sextos will provide 4,317.62 to ama PREPARED BY APPROVED BY ; ic 9.0. seu 198065 —~CS~S*S 222 sw Columbia, sta. 1806 Anchorage, Alaska “***9-0069 T-—‘aad, om 97202 UNREIMBURSED BRADLEY LAKE COSTS UTILITY GUEA MONTH AUGUST 1990 "RETURN NO LATER THAN PROJECT COSTS TOTAL AMOUNT al 1990 FINANCE TEAM PARTICIPATION All travel-related expenses for members of the Finance Team for trips and meetings associated with the sevend financing. A2 1990 LEGAL EXPENSES FOR FINANCING EFFORTS Lagal fees of the Cammittes attorney Saxton will provide relating to the second financing to AERA effort. a3 1990 OPINIONS OF COUNSEL Scope of work on 1990 second financing Mone until requested effort to be determined later. uy ARA aS 1990 TCC EXPENSES Travel asd meting expenses associated with your utility's partisipetion on the Technical Coordinating Committes. Do net include anevats for etaff tine. 318.94 SECTION 31 COSTS (a) S00C-appreved costs fer cenductiog Committee sestings and general business. PREPARED BY APPROVED BY , v forward ccupleted chart to! Sead copy wor Julie Seeker aoa toa Alasks AALAOK , Sart ot. el. 7.0, Bom 190869 222 rolumbia, Ste, 1600 Ancherege, Alaska 99919-0869 Portiand, OB 97201 UNREIMBURSED BRADLEY LAKE COSTS UTILITY GVEA MONTH SEPTEMBER 1990 — "RETURN NO LATER THAN PROJECT COSTS al 1990 FINANCE TEAM PARTICIPATION All travel-related expenses for genbere of the Finance Team for trips and meetings assceiated with the second tinancing. LEGAL EXPENSES FOR FINANCING EFFORTS Legal fees of the Committee attorney relating to the sessnd financing effort. Saxton will provide to ARA OPINIONS OF COUNSEL Sogpe of work on 1990 second financing effort to be determised later. Sone until requested TCC EXPENSES Travel and meeting expenses associated with your utility's participetion on the Sechaical Coordinating Committee. Do not include amounts for staff time. 308.75 SECTION 31 COSTS Mi OK EANM LEAL LO ROO - wend mente One nn tne ne MEL OS BEL OGS 200 Yecere. CUBLOeSS. a Se PREPARED BY APPROVED BY , | We a Municipality of Anchorage Municipal Light & Power Tom Fink, Mayor 1200 East First Avenue Anchorage, Alaska 99501-1685 (907) 279-7671, Telecopiers: (907) 276-2961, 277-9272 November 15, 1990 Ater Wynne Hewitt Dodson & Skerritt Suite 1800 222 S.W. Columbia Portiand, Oregon 97201-6618 Attn; Ron Saxton Re: Reimbursement of Bradiey Lake Costs Dear Mr. Saxton, Attached you will find my expenses for the trip to New York for the Bradley Lake Bond Closing. Summarized, they are: Air travel $1,396.00 Lodging 466.18 Per Diem (Meais) 72.00 Ground transportation 42.00 Telanhone . 108 $1,976.26 These costs have not been included in any prior requests for reimbursement. 2 2 Thomas R, Stabr General Manager Sincerely, CP/jh ce: Marcey Rawitscher. AEA Putting Energy Into Anchorage 11728798 18:42 8 503 226 8079 ATER WYNNE Forward ee a chart “ ak. Seni py tot all avee Ga en” Ron Saxton Alaska Energy durhozity Rew Lindsay, Mart et. al. P.O. Box 190869 222 SW Columbia, Ste. 1800 Anchorage, Alaska 99519-0869 Portland, OR 97201 UNREIMBURSED BRADLEY LAKE COSTS UTILITY Homer Electric AssociationMONTH July, Aug... Sept... Oct, 1990 RETURN NO LATER THAN PROJECT COSTS CATEGORY TOTAL AMOUNT Al 1990 FINANCE TEAM PARTICIPATION All travel-related expenses for members of the Finance Teem for trips and meetings asacciated with the second financing. i390 —_ EXPENSES FORK F ANANCING EYronrs Jean) Clnnnes @avenn wil) nrovide eztor. ine we aun 1890 OPINLUNS OF COUNSEL Scope of work on 1990 secend financing Mone until requested attert to be determined later. by ABA ——: as 14.79 Magee 1990 TCC EXPENSES 136.61 Jume* Travel and meeting expenses associated 283 71 Ju y with your utility’s partiedpetion on 438.47 Aug. the Technical Coerdinating Committees. 17-35) Oc | Do not include amounts for staff time. * Charges listed for May and June not previously submitted. SECTION 31 COSTS BPMC ORGANIZATION 730.45 July (8) BPMC-approved costs for conducting 184.96 Sept. Committees meetings and general business. Legal expenses for representation ries wll Seti of Committee. PREPARED BY (ic. Auntun APPROVED BY Ina Carol A. Hum IN ACCOUNT WITH ATER WYNNE HEWITT DODSON & SKERRITT Lawyers Suite 1600 222 6.W. Columbia Portland, Oregon 97201-6618 Bradley Lake Project Management Committee/Utilities Group Attn: Michael P. Kelly Box 1249 Fairbanks, Alaska 99707 September 24, 1990 For professional services and expenses in August, 1990: General w2.900,81 TOTAL AMOUNT DUE $ 2,900.81 der0Bs. inv IN ACCOUNT WITH ATER WYNNE HEWITT DODSON & SKERRITT Lawyers Suite 1800 222 S.W. Columbia Portland, Oregon 97201-6618 Bradley Lake Project Management Committee/Utilities Group Attn: Michael P. Kelly Box 1249 Fairbanks, Alaska 99707 October 22, 1990 For professional services and expenses in August and Saptember 1990 on the Bond Issue and September 1990 on the General matters: General $ 7,801.46 Bond 12,965.38 TOTAL AMOUNT DUE $20,766.84 dor0@8.inv IN ACCOUNT WITH ATER WYNNE HEWITT DODSON & SKERRITT Lawyers Suite 1800 222 8.W. Columbia Portland, Oregon 97201-6618 Bradley Lake Project Management Committea/Utilities Group Attn: Michael P. Kelly Box 1249 Fairbanks, Alaska 99707 November 20, 1990 For professional services and expenses in October, 1990: General 8,151.87 TOTAL AMOUNT DUE $8,151.87 der 086. {nv DATE: TO: FROM: SUBJECT: skb9484(1) Alaska Energy Authority MEMORANDUM November 26, 1990 Robert E. LeResche Executive Director David R. mene CO- Project Manager: Bradley Lake Project Management Committee - Approval of Homer Electric Association Bradley Junction Costs Attached is an invoice from Homer Electric Association (HEA)for the construction of a dead-end, switching structure at Bradley Junction. This is an additional wood pole structure which had to be constructed in- line with HEA's Fritz Creek-Soldotna line. Because it is a wood pole structure, it was more cost effective to have HEA install the structure concurrent with their transmission line construction last winter, as opposed to including it under the Energy Authority's transmission line contract which would have required a special mobilization to install a single wood pole structure. The Technical Coordination Subcommittee addressed this requirement at several meetings during which it was agreed that this was Bradley Lake project work and could best be accomplished by HEA. The original estimate cost was approximately $50,000. The total final cost for this work is $41,590.24. It is requested that the Project Management Committee approve this as a Bradley Lake project cost and that reimbursement to HEA be authorized. DRE:skb Attachment as stated. ye hae xe. DP KOT HECUOMD COPY FILE NO HMomer Electric Association; CENTRAL OFFICE: 3977 LAKE STREET @ HOMER. ALASKA 99603 @ (907) 235-8167 October 19, 1990. es = - Pipes ny fr | | Dave Eberle se eos pe ALASKA ENERGY AUTHORITY gor ALAS ry 701 East Tudor Road AL P. O. Box 190869 Anchorage, AK 99519-0869 Sree Re: Billing for Bradley Junction Switch Structure Dear Dave; At an early TCS meeting (estimate March 1988) it was agreed that the Bradley Project would reimburse Homer Electric for installation of a switch structure at Bradley Junction. This structure is in-line with the Homer Electric line and is a wood pole H frame structure. It was felt to be impractical to have Newbery gear up to install only one wood pole structure as part of their contract. Construction timing was also recognized as a problem, as it had to be in place for Homer Electric to finish their part of the construction in that area. The structure was installed by Homer Electric personnel as part of our force account construction of the line from Fritz Creek Substation to Bradley Junction. Enclosed is the billing for the force account installation of that structure by Homer Electric. The billing is calculated in accordance with our standard accounting practices for this force account project. Please advise if you need further information. Your prompt handling of this billing would be appreciated. Sincerely, Ata, S.C. Matthews Acting Manager, Engineering AEABILL.SCM/js eo nani FORDENGE DIST TT.” f enclosure : oR eine" PRO 2-41 “ ¢T¢5) D . fom a+7.7 (me Homer Electric Association, Inc. —_—_—_—_-—e-—. e——___—_—— CO ea — CENTRAL OFFICE: 3977 LAKE STREET @ HOMER. ALASKA 99603 @ (907) 235-8167 —_—— October 17, 1990 Alaska Energy Authority c/o Attn: Marcey Rawitscher Finance Manager P.O. Box 190869 Anchorage, AK 99519-0869 Subject: Bradley Junction Towers Member #100214-84 Dear Ms. Rawitscher: Labor figured at $39.71 per man hour: 1-03-90 40 Hours $ 1,588.40 1-04-90 42 Hours 1,667.82 1-05-90 36 Hours 1,429.56 1-08-90 60 Hours 2,382.60 1-09-90 42 Hours 1,667.82 1-10-90 50 Hours 1,985.50 $ 10,721.70 Administrative Overhead x 1.34 $ 14,367.08 Equipment: Unit #208 56 Hours @ $84.00 S$ 4,704.00 Unit #203 20 Hours @ 29.50 $90.00 Unit #909 40 Hours @ 84.00 3,360.00 Unit #908 16 Hours @ 24.25 388.00 Unit #296 20 Hours @ 40.00 800.00 Unit #136 16 Hours @ 24.25 __ 388.00 s 10,230.00 w -_ Bradley Junction Towers = Page 2 Matenal: TH-SA Structure Kit S 712.00 Glass Bells, 54 @ $14.83 800.82 65H2 Poles, 3 @ $1,444.00 4,332.00 Anchors, 12 @ $77.00 924.00 Anchor Rods, 72 @ $87.50 6,300.00 Thimbles, 12 @ $30.00 360.00 Misc. Hardware 500.00 $ 13,928.82 Stores x 1.22 $ 16,993.16 Total Material $ 16,993.16 Total Equipment 10,230.00 Total Labor 14,367.08 Grand Total $ 41,590.24 Sincerely, Samuel C. Matthews Acting Manager, Engineering BRADLEY.SCM:tv DATE: TO: FROM: SUBJECT: RECORD TUOPY FILE NO Alaska Energy Authority MEMORANDUM January 31, 1991 Bradley Lake PMC Members Brent N. Petrie BY ye Alternate Secretary Bradley Lake PMC Meeting - February 22, 1991 This is a notice to inform you that the scheduled Bradley Lake PMC Meeting for February 22, 1991 has changed and the new meeting date is March 5, 1991 at Chugach Electric Association. The meeting time will be at 10:00 a.m. in the Training Room. Please contact DeAnna Scott of my staff if there is a conflict in your schedule. DS/BNP/ds CB Mack 5, 'F9/ won a nlttiy > | Steve Cowper Governor Alaska Energy Authority A Public Corporation THtCeEcOoPr yY (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: ae ieee LIE a NAME OF COMPANY: ae Migr — COMPANY ADDRESS: TELECOPY PHONE NUMBER: 303 — P26 — ee Qor7?e SENDER: Aha ormcen, aS TELEPHONE NUMBER: we LF 2 Pe CHARGE CODE: NUMBER OF PAGES SENT: a2 INCLUDING THIS COVER PAGE DATE SENT: oye IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: = RO. BOK AM JuNne@au. Alaska 99811 — (907) 465-3575 Sa’ PO. Box 190869 701 EastTucter Road) = Anchorage Aicaska 99519-0869 (907) 561-7877 TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT ** COUNT *% # 2 **KK SEND kK No] REMOTE STATION I. D. START TIME DURATION #PAGES COMMENT iI if Re 503 226 0079 2- 4-91 16:09 2°02" 2 TOTAL 0:02'02" 2 XEROX TELECOPIER 7020 State of Alaska DN Steve Cowper, Governor Alaska Energy Authority A Public Corporation TEUEGO PY (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) ¢ ) , TELECOPY SENT TO: — NAME OF COMPANY: Me Uy, pte COMPANY ADDRESS: TELECOPY PHONE NUMBER: 5. _ oly Tl {LB OTE — SENDER: i AS TELEPHONE NUMBER: </~/-“7{ 7 7 CHARGE CODE: NUMBER OF PAGES SENT: ne | INCLUDING THIS COVER PAGE DATE SENT: S-Y-9/ IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: — PO.BoxAM Juneau, Alaska 99811 (907) 465-3575 SW PO. Box 190869 704 East Tudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 State of Alaska om™ Steve Cowper Governor U Alaska Energy Authority & Public Corperation TELECOPY (ANCHORAGE Telecopy Phone No. (907) $61-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: Z Aers as NAME OF COMPANY: ek eee = COMPANY ADDRESS: TELECOPY PHONE NUMBER: Se2 - DONT SENDER: Aha Loan Sarr TELEPHONE NUMBER: = ZZ CHARGE CODE: NUMBER OF PAGES SENT: a2 INCLUDING THIS COVER PAGE DATE SENT: et i Fs IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: = RO. Box AM Juneau, Alaska 99811 (907) 465-3575 BY PO. Box 190869 §=6701 East Tudor Roaa Anchorage Alaska 99519-0869 (907) 561-7877 TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT *%* COUNT ** # 2 RK SEND shake NO REMOTE STATION I. D. START TIME DURATION #PAGES COMMENT i 1 9075620027 2- 4-91 16:17 1°14" 2 E TOTAL 0:01'14" 2 XEROX TELECOPIER 7020 State of Alaska N Steve Cowper. Governor Alaska Energy Authority A Public Corporation TE i Ec 0 pry (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: wid hus ¢ ImAovac NAME OF COMPANY: Bip eaters ge Sonara somes COMPANY ADDRESS: TELECOPY PHONE NUMBER: _ © @od - JOQXT — SENDER: A me bord TELEPHONE NUMBER: Ae(-797 7 CHARGE CODE: NUMBER OF PAGES SENT: od INCLUDING THIS COVER PAGE DATE SENT: eee IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: — PO.BoxAM Juneau, Alaska 99811 (907) 465-3575 SX PO. Box 190869 701 EastTudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 State of Alaska fi cow! TA Ror Ce Steve Cowper, Soverno Alaske Energy Authority A Public Corporation TELEC OP Y (ANCHORAGE Talecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: oe Miles nan y C eee et LE uclor NAME OF COMPANY: COMPANY ADDRESS: TELECOPY PHONE NUMBER: _co7 oe? SJ ~ F2 SF —o TELEPHONE NUMBER: fom “4 77 CHARGE CODE: NUMBER OF PAGES SENT: a INCLUDING THIS COVER PAGE DATE SENT: RHF IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) _ 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: PO. BOX AM Juneau. Alaska 99811 (907) 465-3575 PO. Box 190869 701 EastTucerRoag = Anchorage Alaska 99519-0869 (907) 561-7877 Xi TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT **k COUNT *% # 2 we SEND *k% [no] REMOTE STATION I. D. START TIME DURATION #PAGES COMMENT 1 i| 907 224 3248 2- 4-91 16:26 1°11" 2 L TOTAL 0:01'11" 2 XEROX TELECOPIER 7020 State of Alaska N Steve Cowper, Governor Alaska Energy Authority A Public Corporation TELECOPY (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) _ ( ; TELECOPY SENT TO: fe Ale new ich i NAME OF COMPANY: Le JK 0 Go ue COMPANY ADDRESS: TELECOPY PHONE NUMBER: ee Y ~ 52 9 SENDER: TELEPHONE NUMBER: 9/,/--7¢ 77 CHARGE CODE: NUMBER OF PAGES SENT: A INCLUDING THIS COVER PAGE DATE SENT: A-Y-F/ IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: > — PO.BoxAM Juneau, Alaska 99814 (907) 465-3575 SX PO. Box 190869 701 East Tudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 2K SEND *k%« State of Alaska ca | Steve Cowser. Governo: >» | Alaska Ennergy Authority A Public Corporation v-S_2.-€ 6) 6 PF “¥ (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: Len Atoka Jopames Kha Ce NAME OF COMPANY: IN EF COMPANY ADDRESS: TELEcoPpY PHONE NUMBER: 7GYS —~ PZ2F7 SENDER: TELEPHONE NUMBER: f- Saas. CHARGE CODE: NUMBER OF PAGES SENT: INCLUDING THIS COVER PAGE DATE SENT: IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) _ 261-7240~Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: = PO BOK AM JuNne@au. Alaska 99811 (907) 465-3575 SY PO. Box 190869 701 EastTucter Roaa Anchorage Alaska 99519-0869 (907) 561-7877 TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT ** COUNT ** # 2 NO REMOTE STATION I. D. | START TIME DURATION #PAGES COMMENT 1 9077453328 | 2- 4-91 16:33 coe 2 | TOTAL 0:01'21" 2 XEROX TELECOPIER 7020 State of Alaska DS Steve Cowper. Governor Alaska Energy Authority A Public Corporation TELECOPY (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: Yn Rutekes [Lc Vanes KJ alk NAME OF COMPANY: | Ex EX COMPANY ADDRESS: TELECOPY PHONE NUMBER: TYS = 93,25 SENDER: TELEPHONE NUMBER: §<Ole/-“)&-77 CHARGE CODE: NUMBER OF PAGES SENT: INCLUDING THIS COVER PAGE DATE SENT: IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: , — PO.BoxAM Juneau, Alaska 99811 (907) 465-3575 X PO. Box 190869 701 East Tudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 Store of Alaska ™ Steve Cowper, Governor Alaska Brergy Authority A Public Corporation TELECOPY (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: As SX. Bley ae MM afew s NAME OF COMPANY: Le reece FEZ a -fee~ a soll eagle COMPANY ADDRESS: TELECOPY PHONE NUMBER: eo? 35--FY7%R SENDER: Mh Lb nr | pecs TELEPHONE NUMBER: SGol--7F 77 CHARGE CODE: NUMBER OF PAGES SENT: =<? INCLUDING THIS COVER PAGE DATE SENT: w= S- Fr IF YOU BDO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: PO. BOX AM Juneau. Alaska 998141 (907) 468-3575 - PO. Box 190869 701 EastTucior Road) = Anchorage, Alaska 99519-0869 (907) 541-7877 x! TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT *k COUNT *%* # 2 *wkKK SEND kK | NO REMOTE STATION I. D. - START TIME DURATION #PAGES COMMENT | T 1 2358496 | 2- 4-91 16:35 1°11" 2 TOTAL 0:01'11" 2 XEROX TELECOPIER 7020 State of Alaska DS Steve Cowper, Governor Alaska Energy Authority A Public Corporation Tree GoO Pp y (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: HZ. 4 il Ma Lhews NAME OF COMPANY: (MEX ee 7 ea ar COMPANY ADDRESS: TELECOPY PHONE NUMBER: 01 3.9 -¥ YIC ) — SENDER: Uy N11 ar TELEPHONE NUMBER: _(o/~“75 77 CHARGE CODE: NUMBER OF PAGES SENT: =! INCLUDING THIS COVER PAGE DATE SENT: J- Y-F/ IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: — PO.BoxAM Juneau, Alaska 99811 (907) 465-3575 3 PO. Box 190869 704 East Tudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 State of Aiaske y } j Steve Cowper Governor > Alaska Brnergy Authority & Public Corporation TEL &-coT ¥ (ANCHORAGE Telecopy Phone No. (907) 561-8584) (SUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: NAME OF COMPANY: COMPANY ADDRESS: TELECOPY PHONE NUMBER: oe 2lLe -—o Fae Z winonn: 02 Mobaaeee BAe TELEPHONE NUMBER: Sal - Fe a. CHARGE CODE: NUMBER OF PAGES SENT: oZ INCLUDING THIS COVER PAGE DATE SENT: ——/— IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (9072, 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: = RO. 80K AM Juneau. Alaska 99611 (907) 465-3575 BS FO. Box 190869 86701 East Tucior Road = Anchorage, Alaska 99519-C869 (907) 561-7877 TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT **k COUNT *#% # 2 we SEND KK NO REMOTE STATION I. D. START TIME DURATION #PAGES COMMENT Vy 907 276 2961 2- 4-91 16:45 12 2 TOTAL 0:01'12" 2 XEROX TELECOPIER 7020 State of Alaska DN Steve Cowper, Governor Alaska Energy Authority A Public Corporation TEL-EGOP Y (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: NAME OF COMPANY: COMPANY ADDRESS: TELECOPY PHONE NUMBER: = G7 /lo — I Fe SENDER: TELEPHONE NUMBER: Q/./~ 7 7 7 CHARGE CODE: NUMBER OF PAGES SENT: a INCLUDING THIS COVER PAGE DATE SENT: Q-G-F/ IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: . = PO. BoxAM Juneau, Alaska 99811 (907) 465-3575 XM PO. Box 190869 701 EastTudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 State of Alaska steve owner Governor } Alaska Gnergy Authority A Public Corporation TEGLEcOo pry (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 468-3767) TELECOPY SENT TO: Pika Lacey Leak Apart seo Pe rei NAME OF COMPANY: COMPANY ADDRESS: TELECOPY PHONE NUMBER: YS /~SCS ea eee ere SENDER: TELEPHONE NUMBER: Fle l=<-2<— 7Z CHARGE CODE: NUMBER OF PAGES SENT: ee INCLUDING THIS COVER PAGE DATE SENT: aw —- IS IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) _ 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: PO. Box AM Jun@au. Alaska 99811 (907) 465-3575 . Box 190869 701 East Tuder Road) Anchorage Alaska 99519-0869 (907) 561-7877 Mii TRANSMISSION REPORT THIS DOCUMENT (REDUCED SAMPLE ABOVE) WAS SENT **k COUNT ** # 2 %*RK SEND 2K iNo| REMOTE STATION I. D. START TIME | DURATION | PAGES COMMENT 1 4515633 2- 4-31 16:51 | ium 2 TOTAL 0:01°12" 2 XEROX TELECOPIER 7020 State of Alaska DN Steve Cowper, Governor Alaska Energy Authority A Public Corporation ThE LEG 0) RP ¥ (ANCHORAGE Telecopy Phone No. (907) 561-8584) (JUNEAU Telecopy Phone No. (907) 465-3767) TELECOPY SENT TO: MWe Le Ub, / Job Wan se NAME OF COMPANY: LVED COMPANY ADDRESS: TELECOPY PHONE NuMBER: _ 79 /~ SG ao SENDER: TELEPHONE NUMBER: Fal-VE 77 CHARGE CODE: NUMBER OF PAGES SENT: aa INCLUDING THIS COVER PAGE DATE SENT: Ef -F J IF YOU DO NOT RECEIVE ALL OF THIS TELECOPY PLEASE CALL: (907) 261-7240-Anchorage (907) 465-3575-Juneau SPECIAL INSTRUCTIONS: , = PO.BoxAM Juneau, Alaska 99811 (907) 465-3575 3 PO. Box 190869 704 East Tudor Road Anchorage, Alaska 99519-0869 (907) 561-7877