Independent Power Producers Association of BC Information Request No. 1.50.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
50.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8; Volume 2, Appendix I The Application claims that over the 10 Year (Power Smart ) Plan, Stepped Rates will only reduce the need for Power Smart incentive payments to Industrial customers by $60 million. Total BC Hydro Costs (Power Smart) for the Industrial Sector from F2005 to F2012 is approximately $221 million (Appendix I – 10 Yr Plan).
1.50.1
Please confirm that the evaluations and investment in industrial incentives proposed in the 10 Year Plan were determined using the rate structure of 2003, absent consideration of future rate increases, stepped rates and time-of-use rates. If not fully explain the assumptions made regarding industrial rates when the 10 Year Plan was prepared.
RESPONSE: Please see the Power Smart 10-Year Plan, Appendix A – Alternative Scenarios (page 29), which sets out the assumptions for rate structures for the base case used in the Application and the scenarios contained in the Power Smart 10-Year Plan.
Independent Power Producers Association of BC Information Request No. 1.50.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
50.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8; Volume 2, Appendix I The Application claims that over the 10 Year (Power Smart ) Plan, Stepped Rates will only reduce the need for Power Smart incentive payments to Industrial customers by $60 million. Total BC Hydro Costs (Power Smart) for the Industrial Sector from F2005 to F2012 is approximately $221 million (Appendix I – 10 Yr Plan).
1.50.2
Please indicate all assumptions made in respect of increasing rates, stepped rates and time-of-use rates supporting the declaration that payments to Industrial customers will decline by $60 million.
RESPONSE: BC Hydro’s response to BCUC IR #1.55.1 provides further elaboration on how stepped rates implementation impacts Power Smart by a reduction of $60 million in incentives and program costs. Based on the CPR an estimated conservation potential for each Rate 1821 customer was developed, by industry. Savings estimates from anticipated load displacement projects and other major projects not considered in the CPR were then added to estimate the DSM potential for each Rate 1821 customer. For customers whose total DSM savings were estimated to be less than 10% of their current consumption level, it was assumed they would no longer require an incentive because the entire DSM potential for these particular customers falls within Tier 2 of the stepped rate. This amounted to about 40% of the industrial DSM identified in the Power Smart 10-Year Plan. For customers whose total DSM savings were estimated to be greater than 10% of their annual usage, it was assumed they would require incentives for all of their conservation and load displacement projects and that an appropriate adjustment would be made to the customer’s CBL. This analysis was used as the basis for the analyses described in Appendix A of the Power Smart 10-Year Plan.
Independent Power Producers Association of BC Information Request No. 1.50.3 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
50.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8; Volume 2, Appendix I The Application claims that over the 10 Year (Power Smart ) Plan, Stepped Rates will only reduce the need for Power Smart incentive payments to Industrial customers by $60 million. Total BC Hydro Costs (Power Smart) for the Industrial Sector from F2005 to F2012 is approximately $221 million (Appendix I – 10 Yr Plan).
1.50.3
Please explain why Power Smart programs for large electricity consumers should not be eliminated when the purpose of stepped rates is to provide the price signal to large electricity consumers for those consumers to self-invest in conservation and energy efficiency.
RESPONSE: Please see BC Hydro’s response to IPPBC IR #1.49.1.
Independent Power Producers Association of BC Information Request No. 1.50.4 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
50.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8; Volume 2, Appendix I The Application claims that over the 10 Year (Power Smart ) Plan, Stepped Rates will only reduce the need for Power Smart incentive payments to Industrial customers by $60 million. Total BC Hydro Costs (Power Smart) for the Industrial Sector from F2005 to F2012 is approximately $221 million (Appendix I – 10 Yr Plan).
1.50.4
Does BC Hydro agree that there is no reasonable Stepped Rate or Time-of-Use rate for large electricity consumers that would be sufficient to eliminate Power Smart incentives for these large electricity consumers? If not, explain.
RESPONSE: Due to limitations of rate design it is unlikely that the role of Power Smart incentives could be entirely eliminated.
Independent Power Producers Association of BC Information Request No. 1.51.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
51.0
Reference:
Application, Volume 1, Chapter 4, p. 7 The Application states: “Programs targeting this market screen projects based on the customer’s return on investment with and without an incentive from BC Hydro.”
1.51.1
Please provide a copy of the policy document, or like, which guides BC Hydro management in determining whether to provide a Power Smart incentive for industrial customers. Ensure that all documentation addresses the policy for each of “Power Smart Partner” programs and “Load Displacement” programs including the energy conservation and self-generation programs.
RESPONSE: Please see BC Hydro’s response to SIERRA IR #1.12.0.
Independent Power Producers Association of BC Information Request No. 1.51.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
51.0
Reference:
Application, Volume 1, Chapter 4, p. 7 The Application states: “Programs targeting this market screen projects based on the customer’s return on investment with and without an incentive from BC Hydro.”
1.51.2
Please provide a list of each industrial customer and the DSM program which is to obtain full or partial incentive payments, Power Smart or otherwise, in F2004, F2005 and F2006. For each of these customers, provide the program evaluation documentation, or like, which demonstrates the return on investment for the customer DSM program before and after the incentive. If the return on investment was not calculated in the form of an Internal Rate of Return (“IRR”) provide the IRR for each program before and after the BC Hydro incentive payments.
RESPONSE: Specific information on customer projects and Power Smart investment levels is confidential. Unless the customer agrees to release information on the project (typically accompanied by a public news release on the project), the material remains confidential. As a result, it is inappropriate to provide a list of industrial customer projects that are currently being analyzed. There will be additional projects received through the competitive process in the next two years that will also receive full or partial payments in F2005 or F2006. Project details are unavailable until a customer application has been received by BC Hydro.
Independent Power Producers Association of BC Information Request No. 1.51.3 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
51.0
Reference:
Application, Volume 1, Chapter 4, p. 7 The Application states: “Programs targeting this market screen projects based on the customer’s return on investment with and without an incentive from BC Hydro.”
1.51.3
For each of the customers and programs identified in the above question, please indicate whether the original evaluation of the customer’s return on investment reflected the rate increase of this Application and/or a stepped rate. Identify all assumptions made in each case. If the original evaluation did not consider the rate increase and stepped rates, please provide the return on investment under these conditions, with and without the BC Hydro incentive.
RESPONSE: No customers are identified in BC Hydro’s response to IPPBC IR #1.51.2. The financial analyses performed on project applications since the Application was filed incorporate the general rate increase applied for in the Application. Any potential Stepped Rate or Time-of-Use rate structure has not been incorporated into the financial analysis.
Independent Power Producers Association of BC Information Request No. 1.52.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
52.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8 The application states, “A rate increase would result in some projects becoming sufficiently economically attractive for the customer to consider without an incentive. These projects would be screened from the program, resulting in a decrease in energy savings attributed to the program and incentive costs needed for the program. A rate increase would also result in previously unattractive projects becoming attractive enough for the customer to pursue with an incentive.” [emphasis added]
1.52.1
Please clarify if this statement was intended to apply to programs in which incentive payments are being made in F2004, F2005 or F2006, or whether it was intended to address programs throughout the 10 year plan.
RESPONSE: The statement on Chapter 4, Page 4-7, Line 30 to Page 4-8, Line 1 is applicable to program responses throughout the 10-Year Plan.
Independent Power Producers Association of BC Information Request No. 1.52.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
52.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8 The application states, “A rate increase would result in some projects becoming sufficiently economically attractive for the customer to consider without an incentive. These projects would be screened from the program, resulting in a decrease in energy savings attributed to the program and incentive costs needed for the program. A rate increase would also result in previously unattractive projects becoming attractive enough for the customer to pursue with an incentive.” [emphasis added]
1.52.2
Please provide a list of industrial DSM programs which have been commenced in F2004, or will be commenced in F2005 and F2006, that were previously unattractive at the industrial rate of $34/MWh but have now become attractive for the customer to pursue without a Power Smart incentive when industrial rates is at an average rate of $37.2/MWh (Chapter 2, p.7) and includes a Tier 2 price set at the longrun incremental cost of supply, say $55/MWh.
RESPONSE: The Power Smart Partners program is the predominant incentive based program for industrial customers. Industrial customers that become Power Smart Partners are eligible to apply for incentives for customer projects. As part of the financial evaluation, applications are now assessed using the general rate increase. As noted in the statement referred to above, an increase in rates will result in some projects being screened from the program as the projects should be attractive to the customer without an incentive. This decrease will be offset by projects that were otherwise unattractive to customers even with an incentive becoming attractive enough to pursue with an equal or lesser incentive.
Independent Power Producers Association of BC Information Request No. 1.52.3 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
52.0
Reference:
Application, Volume 1, Chapter 4, p. 7, 8 The application states, “A rate increase would result in some projects becoming sufficiently economically attractive for the customer to consider without an incentive. These projects would be screened from the program, resulting in a decrease in energy savings attributed to the program and incentive costs needed for the program. A rate increase would also result in previously unattractive projects becoming attractive enough for the customer to pursue with an incentive.” [emphasis added]
1.52.3
If BC Hydro cannot provide a list of projects, please explain the basis for declaring that “it is assumed that these opposing forces would roughly offset one another [sic]”. (page 8)
RESPONSE: The basis for the assumption is that the size of the two opposing effects is unknown, and there is no evidence to suggest that they would not be symmetrical.
Independent Power Producers Association of BC Information Request No. 1.53.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
53.0
Reference:
Application, Volume 1, Chapter 4, p.12 BC Hydro establishes a “benchmark for acquisitions” as the levelized cost of near-, medium- and long-term forecasts of future electricity prices. Since F2001, this benchmark has been approximately $55/MWh.
1.53.1
Please provide the current version of the near, medium and long-term forecasts and show how BC Hydro calculates a levelized cost of approximately $55/MWh. Show and discuss all assumptions.
RESPONSE: The table below shows BC Hydro’s version of its 20 year levelized electricity market price forecast. Assumptions used in the levelizing calculation are as follows: • Electricity Price Forecast: For more information on how BC Hydro derives its Electricity Price Forecast, please see BC Hydro’s response to SIERRA IR #1.7.0 as well as Addendum 1 to the VI Call for Tenders which is posted on BC Hydro’s website at: http://www.bchydro.com/rx_files/info/info8875.pdf. BC Hydro calculates price forecasts for both the BC Lower Mainland and Mid-C. In the table below, the price forecast for the BC Lower Mainland is used. The prices indicated are real 2003 calendar prices and are based on the most current (January 2004) BC Hydro Price Forecast. Please note that a previous forecast was used to calculate the levelized cost of $55/MWh. Discount rate: The discount rate represents an after-tax, time value of money for a utility. In this example, a 6% real discount rate is assumed.
•
Independent Power Producers Association of BC Information Request No. 1.53.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 2
Present Value Factor Calendar Calendar with 6% Real Price (Real Discount 2003 $/MWH) Year Rate A B 2005 1.00 48.3 2006 0.94 47.1 2007 0.89 41.5 2008 0.84 42.8 2009 0.79 43.5 2010 0.75 43.7 2011 0.70 45.2 2012 0.67 47.5 2013 0.63 50.4 2014 0.59 50.5 2015 0.56 50.9 2016 0.53 51.0 2017 0.50 51.1 2018 0.47 51.0 2019 0.44 51.0 2020 0.42 51.3 2021 0.39 51.8 2022 0.37 51.7 2023 0.35 51.7 2024 0.33 51.7 Totals
PV of Calendar Price C=AxB 48.3 44.4 37.0 36.0 34.5 32.6 31.8 31.6 31.6 29.9 28.4 26.9 25.4 23.9 22.5 21.4 20.4 19.2 18.1 17.1 581.1
PV of 1 MWh of Energy D=Ax1 1.00 0.94 0.89 0.84 0.79 0.75 0.70 0.67 0.63 0.59 0.56 0.53 0.50 0.47 0.44 0.42 0.39 0.37 0.35 0.33 12.16
Levelized Price = Sum(C) ÷ Sum(D) = 47.8 Real $/MWh
Independent Power Producers Association of BC Information Request No. 1.54.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.1
Please provide a breakdown list of all projects included in this category and their capital expenses.
RESPONSE: Please see the tables below for a list of significant projects (with total cost greater than $2 Million) with expenditures in F2005 or F2006 that are planned to be in service after F2006, broken down by group. All dollar figures are quoted in $millions.
Independent Power Producers Association of BC Information Request No. 1.54.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 2
Project Name
TRANSMISSION / BCTC Mission and Matsqui Area - 69 kV Reinforcement IPP Interconnections Rainbow - 25 kV Feeder Section Addition NITS - Meridian 500 kV Capacitor Bank NITS - Selkirk Shunt Reactor NITS - Nicola Shunt Reactor Mainwaring - 230/12 kV Transformers Replacement NITS - ING Shunt Reactor NITS - Ingledow - CB Replacements NITS - Nicola 500 kV Capacitor Bank Mainwaring - 12 kV Feeder Section Addition Highland - 138/69 kV Transformer Replacement Annacis - Low Voltage Facilities Upgrade NITS - 5L91/98 Series Compensation/CB replacements Mt. Pleasant Area Supply NITS - Selkirk Transformers (T2, T3) Langley Area - System Reinforcement Maintain Process IT requirements - Mobile Inspection, Project Management, Project Scheduling, SCADA RTU Replacements - 2004 to 2006 Window 2000 - Pilot Project #2 500 kV Line Protection Replacement - Stage 5 Transmission Control Modernization NITS - Ingledow - 500 KV Fort St. John - 138/25 kV Substation NITS - ING 500 kV Capacitor Bank Maple Ridge Area Capacity Increase Metro 230 kV Supply - Sperling to Downtown Vancouver 60L51/53 Cable - Seismic Upgrade Horsey - Series Reactor Replacement (1) 500 kV Line Protection Replacement - Stage 6 Nicola - Station Reconfiguration NITS - Barnard SVC NITS - Meridian SVC Goward - 230/138 kV Reinforcement NITS - Vancouver Island 230 kV Supply
Sustain/ Growth
Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth Growth
In Service Date
F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007
F2005
10.0 7.8 1.3 1.1 0.7 0.7 0.7 0.5 0.5 0.3 0.3 0.2 0.0 9.5 2.7 2.7 1.6
Est Cost at F2006 Completion
7.3 23.5 3.0 5.3 3.4 3.4 3.4 2.5 2.5 1.7 1.5 1.4 1.4 41.4 6.3 11.2 4.3 33.1 78.4 8.4 9.8 6.2 6.2 9.1 4.6 4.6 5.7 6.3 4.4 4.3 94.2 26.4 27.3 21.6
Sustain Sustain Sustain Sustain Sustain Growth Growth Growth Growth Sustain Sustain Sustain Sustain Growth Growth Growth Growth Growth
F2007 F2007 F2007 F2007 F2007 F2008 F2008 F2008 F2008 F2008 F2008 F2008 F2008 F2009 F2009 F2009 F2009 F2009 F2009 F2009 F2010 F2012
1.0 0.1 0.1 0.0 23.6 1.4 0.7 0.4 0.2 0.1 0.1 0.3 1.2 0.2 0.2 0.0 4.3 0.1 0.4 0.6 2.0 $ 77.6
0.5 3.1 0.2 2.6 28.3 2.8 2.7 1.9 1.1 1.0 0.3 0.3 0.0 1.3 0.9 1.1 0.0 3.8 2.8 0.2 0.8 4.3 $ 183.3
2.0 3.7 0.3 3.6 105.0 38.0 16.0 12.1 7.3 30.5 2.8 1.1 3.7 10.6 33.1 33.1 11.3 199.2 6.6 1.2 11.3 257.4 1,140.2
2L32 (Horne Payne to Murrin #2) - Seismic Upgrade Sustain Transmission Line Reclosing Remote On/Off Control Sustain Transmission System - Ice Hazard Risk Reduction NITS - 5L83 - Nicola to Meridian TRANSMISSION / BCTC Total Sustain Growth
$
Note (1) - Table 6-18 of the Application shows a total of $43.0m for this project. This includes future line projects that commence after stage 6 (F2008) with an in service date of F2013. As well, the timing of the expenditures for the stage 6 project has changed since the filing of the Application (to $0.01m for F2006).
Independent Power Producers Association of BC Information Request No. 1.54.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 3
Project Name
GENERATION Vancouver Island Generation Project Georgia Strait Crossing Coquitlam Dam Seismic Improvements Ruskin Dam Strengthening of Concrete Dam John Hart Penstock 1 Replacement and PRV GM Shrum Unit Transformers and Generators Protection Strathcona Embankment Dam Improvements LaJoie Dam Safety Improvements GM Shrum Unit 8 Capacity Increase Aberfeldie Redevelopment Mica Unit 4 Stator Replacement Peace Canyon Generator Deficiency Project GENERATION Total
Sustain/ Growth
Growth Growth Sustain Sustain Sustain Sustain Sustain Sustain Sustain Growth Sustain Sustain
In Service Date
F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2007 F2008 F2008 F2009
F2005
25.0 32.7 3.0 0.7 0.5 1.1 0.2 1.8 0.4 1.0 0.4 0.8 $ 67.6
Est Cost at F2006 Completion
122.9 69.7 8.8 15.0 13.7 2.3 3.0 4.0 2.1 1.5 2.7 10.6 $ 256.3 370.0 208.5 40.0 30.8 15.1 8.9 7.2 6.3 4.3 51.6 12.8 46.0 801.5
$
Project Name
DISTRIBUTION Northstar CRM and Business Warehouse DISTRIBUTION Total
Sustain/ Growth
Sustain
In Service Date
F2007
F2005
Est Cost at F2006 Completion
5.0 5.0 10.0 10.0
-
$
$
Project Name
CORPORATE Peoplesoft PAHR Upgrade / Enhancements Peoplesoft Financials Upgrades Passport Web Procurement CORPORATE Total
Sustain/ Growth
Maintain Maintain Enabling
In Service Date
F2007 F2007 F2007
F2005
0.8 0.7 $ 1.5
Est Cost at F2006 Completion
3.5 3.5 1.5 8.5 9.6 9.3 2.0 20.9
$
$
Independent Power Producers Association of BC Information Request No. 1.54.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.2
Please explain how BC Hydro finances expenditures for capitalized projects that have not become operational.
RESPONSE: All capital projects, similar to all BC Hydro’s cash requirements, are funded as much as possible through cashflow from operations. To the extent that there are differences in timing between cash inflows and outflows, BC Hydro will utilize revolving borrowings if the cash requirement is temporary or long-term debt if the cash shortfall will be longer in duration. In general, BC Hydro uses this portfolio approach to fund any cash requirements and does not issue specific financing to meet the obligations of a particular project.
Independent Power Producers Association of BC Information Request No. 1.54.3 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.3
Please explain if BC Hydro is accumulating an account for “Allowance for Funds Used during Construction” or “interest during construction” or other form of cost of capital associated with the “capitalized projects”. Please explain how BC Hydro includes such cost of capital in the revenue requirement, and in particular, the F2005 and F 2006 revenue requirement.
RESPONSE: BC Hydro is accumulating interest during construction. BC Hydro’s policy for capitalizing interest during construction (IDC) is included in its response to BCUC IR #2.198.4.1. Forecast F2005 and F2006 finance charges capitalized are shown in Chapter 2, Page 2-13, Table 2-12. The forecast IDC is included in the capital expenditures shown in Chapter 11, Page 11-2, Table 11-2 and is a reduction to finance charges as shown in Table 2-12.
Independent Power Producers Association of BC Information Request No. 1.54.4 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.4
Please confirm that the expenditures associated with GSX and VIGP are solely the expenditures of BC Hydro to develop a generation project which would have, if developed, become a part of the Heritage portfolio. If not, explain.
RESPONSE: The Georgia Strait Pipeline Crossing (GSX) and Vancouver Island Generation Project (VIGP) are not Heritage Resources. Forecast capital expenditures for these projects included in Chapter 11, Page 11-2, Table 11-2 are BC Hydro’s portion of forecast capital expenditures. Please see BC Hydro’s response to BCUC IR # 1.8.3 for further information. The natural gas-fired VIGP was designed to meet load growth on Vancouver Island and to replace the ageing submarine HVDC transmission cables currently providing electricity to the Island. As offered by BC Hydro, and encouraged by the BCUC, a Call for Tenders (CFT) for capacity and associated energy on Vancouver Island has been initiated. GSX is a joint project sponsored by BC Hydro and Williams Gas to construct a natural gas pipeline from the Huntingdon/Sumas supply hub to Vancouver Island. GSX was designed as a large-capacity pipeline with capability to provide gas transportation service to the Island Cogeneration Plant, the planned VIGP, a third gas fired generation plant on Vancouver Island and other large industrial gas consumers along its route through the United States. The outcome of the Vancouver Island CFT will determine whether a private-sector development of VIGP assets or a suite of other projects will be developed. The GSX project is contingent upon development of VIGP or a similar large gas-fired generation plant on Vancouver Island. If the projects proceed, BC Hydro intends to recover the capitalized cost of development in the proceeds from the GSX tolling arrangement and the VIGP project sale to private sector developers. If GSX and VIGP are not developed, BC Hydro will apply to the BCUC for inclusion of sunk costs in future rates.
Independent Power Producers Association of BC Information Request No. 1.54.5 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.5
If GSX and VIGP are developed, please explain how BC Hydro proposes allocating the capitalized and financing costs.
RESPONSE: Please see BC Hydro’s response to IPPBC IR #1.54.4.
Independent Power Producers Association of BC Information Request No. 1.54.6 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
54.0
Reference:
Application, Volume 1, Chapter 4, p. 20 The application notes that GSX and VIGP are the most significant expenditures in the category of “capitalized projects” not reflected in the Test Period revenue requirement.
1.54.6
If GSX and VIGP are not developed, please explain BC Hydro’s preferred method of allocating the stranded capitalized and financing costs.
RESPONSE: Please see BC Hydro’s response to IPPBC IR #1.54.4.
, p.
Independent Power Producers Association of BC Infonnation Request No. 1. 55. 1 Dated: 2 March 2004 BC Hydro Response REVISION 1 , 7 May 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page
55.
Reference:
55.
Application , Volume 1 , Chapter 4
27 (Table 4- 11)
Please provide Table 4- 11 on a monthly basis for F2004 , F2005 and F2006.
RESPONSE:
The tables in this revised response reflect updated information on energy supply volumes for Energy Purchase Agreements Contracted before F2001. Specifically, the volumes have been changed to reflect the actual generation volumes for the period of April to September 2003 as well as revisions to the monthly forecast values for the
remainder of F2004 and the monthly values for F2005 and F2006. The yearly totals have not changed.
Independent Power Producers Association of BC Information Request No. 1. 55. 1 Dated: 2 March 2004 BC H dro Response REVISION 1, 7 May 2004 British Columbia Hydro & Power Authority Revenue Requirements lication 2004/05 and 2005/06
Page
2004 by Month
IGWhl
F2004
Apro03
F2004
Mayo03
F2004 Juno03
F2004
Julo03
F2004
AUQo03
F2004
F2004
F2004
Novo03
F2004
Deco03
Sepo03
Oct.
F2004 Jano04
F2004 Febo04
F2004
Maro04
Energy Requirements before Power Smart (Note 1): Reference Load Forecast before Power Smart High Forecast before Power Smart Low Forecast before Power Smart
339
277
837
185
135
021
539
848
272
294
904
912
Energy Requirements with Power Smart (Note 2):
Reference Load Forecast with Power Smart
High Forecast with Power Smart Low Forecast with Power Smart
Reduction in Energy Requirements due to Power Smart
317
255
817
164
113
001
516
823
245
267
879
886
Supply
Heritage Resources:
Heritage Hydro (Note 3) Heritage Thermal (Note 4) Market Purchases (Note 4)
517
589 115
646
004 450 3,454
396 213 620
3,441
916 296 250
408
857
604
523
196 721
827
606
819
Total Heritage Resources
Committed New Resource Smart (Note 5) Purchases (Note 6): Energy Purchase Agreements Contracted before F2001 2000 Expression of Interest for Green Energy 2001 Green Energy Call 2002 Customer Based Generation 2002 Green Power Generation
928 579
157 609
445 857
412 272
656
4,437
587 4,409
455
392
426
542
512
509
533
514
555
513
410
443
PlannedNewResourceSmart(Note7)
Vancouver Island Call for Tender(Note8) Total Purchases
457
572
417 996
(281)
454
908
591
558 167
553
803
(219)
578
555 827
(21)
592 248
(24)
551
445 882
(22)
480
888
(23)
Total Supply
Energy Balance: Supply less Forecast Demand before Power Smart
Enernv Balance Based on Hioh Forecast Enerov Balance Based on Low Forecast
211
435
(103)
272
(22)
233
Energy Balance: Supply less Reference Forecast with Power Smart (Note 9) (Note 10) Enerov Balance Based on Hioh Forecast Energy Balance Based on Low Forecast
255
(260)
(198)
(80)
Independent Power Producers Association of BC Information Request No. 1. 55. 1 Dated: 2 March 2004 BC H dro Res onse REVISION 1, 7 Ma 2004 British Columbia Hydro & Power Authority Revenue Requirements lication 2004/05 and 2005/06
Page
2005 by Month
(GWh)
F2005 Apr-
F2005 May-
F2005
F2005
Jun043
Jul.04
F2005 Aug-04
F2005
Sep-
F2005 Oct-04
F2005 Nov-04
F2005 Dec-
F2005
Jan5,432
F2005 Feb-
F2005 Mar-
Energy Requirements before Power Smart (Note 1):
Reference Load Forecast before Power Smart
High Forecast before Power Smart Low Forecast before Power Smart
Energy Requirements with Power Smart (Note 2):
374
245
157
220
093
603
958
383
843
024
Reference Load Forecast with Power Smart
High Forecast with Power Smart Low Forecast with Power Smart
Reduction in Energy Requirements due to Power Smart
300
173
975
087
149
024
526
876
293
341
762
940
Supply
Heritage Resources:
Heritage Hydro (Note 3) Heritage Thermal (Note 4) Market Purchases (Note 4)
326
361
210 347 558
243
120 380
3,414
3,4 72
369
800
120
921
200 289 523
650
684
708
781
060 253 315
093 355 4,450
Total Heritage Resources
Committed New Resource Smart (Note 5) Purchases (Note 6): Energy Purchase Agreements Contracted before F2001 2000 Expression of Interest for Green Energy 2001 Green Energy Call 2002 Customer Based Generation 2002 Green Power Generation Planned New Resource Smart (Note 7) Vancouver Island Call for Tender (Note 8)
438 803 444
423 786
303
3,409
512
313
568
554
525
555
513
403
443
Total Purchases
Total Supply
Energy Balance: Supply less Forecast Demand before
497 497 300
(74)
386 387 173
(72)
416 416 974
(68)
707 707 087
(70)
676 676 148
(71)
615
024
(69)
604
526
(78)
586
876
(83)
608 292
(91)
560
447
762
(81)
490 940
(85)
342
(91)
Power Smart Enerov Balance Based on Hiah Forecast
Enerov Balance Based on Low Forecast
Energy Balance: Supply less Reference Forecast with Power Smart (Note 9) (Note 10) Enerov Balance Based on Hiah Forecast Energy Balance Based on Low Forecast
(0)
(0)
(0)
(0)
(0)
(0)
(1)
(1)
(1)
(0)
(1)
Independent Power Producers Association of BC Information Request No. 1. 55. 1 Dated: 2 March 2004 BC H dro Res onse REVISION 1, 7 Ma 2004 British Columbia Hydro & Power Authority Revenue Requirements lication 2004/05 and 2005/06
Page
2006 by Month
IGWhl
F2006
Apr'(5
F2006 May'(5
F2006
F2006
F2006
Aug.( 5
F2006
F2006
F2006
Nov.( 5
F2006
F2006
F2006
Feb'( 6
F2006 l
Jun'(5
Jul'(5
Sep'(5
Oct'(5
Dec'(5
Jan'(6
Mar'(6
Energy Requirements before Power Smart (Note 1): Reference Load Forecast before Power Smart High Forecast before Power Smart Low Forecast before Power Smart
4,461
311
099
215
282
155
662
026
5,451
513
910
094
Energy Requirements with Power Smart (Note 2):
Reference Load Forecast with Power Smart
High Forecast with Power Smart
352
205
997
111
176
052
548
903
318
380
790
970
Low Forecast with Power Smart
Reduction in Energy Requirements due to Power Smart
109
106
102
104
106
103
114
123
133
133
120
124
Supply
Heritage Resources:
Heritage Hydro (Note 3) Heritage Thermal (Note 4) Market Purchases (Note 4)
3,454 377 843
968 673 643
956 456 3,414
397
3,494
3,431
939
307
309
700
811
323
4,471
Total Heritage Resources
Committed New Resource Smart (Note 5) Purchases (Note 6): Energy Purchase Agreements Contracted before F2001 2000 Expression of Interest for Green Energy 2001 Green Energy Call
3,402
3,498
3,435
941
702
813
325
4,473
441
445
444
568
554
512
525
523
555
514
414
444
2002 Customer Based Generation
2002 Green Power Generation Planned New Resource Smart (Note 7) Vancouver Island Call for Tender (Note 8)
Total Purchases
Total Supply
Energy Balance: Supply less Forecast Demand before Power Smart
Enerav Balance Based on Hiah Forecast Enerav Balance Based on Low Forecast
508
351
561
582
708
110
(105)
678
175
(107)
615
051
605 547
(116)
594 903
(123)
615
567
381
464
789
(120)
496
970
(125)
204
(107)
996
(103)
317
(135)
(110)
(104)
(133)
Energy Balance: Supply less Reference Forecast with Power Smart (Note 9) (Note 10)
Enerav Balance Based on HiNh Forecast Enerav Balance Based on Low Forecast
(1)
(1)
(1)
(1)
(1)
(1)
(2)
(0)
(2)
(0)
(1)
Independent Power Producers Association of BC Information Request No. 1. 55. 1 Dated: 2 March 2004 BC H dro Res onse REVISION 1 J 7 Ma 2004 British Columbia Hydro & Power Authority Revenue Requirements lication 2004/05 and 2005/06
Page
Yearly Totals:
(GWh)
F2004
F2005
F2006
Energy Requirements before Power Smart (Note 1):
Reference Load Forecast before Power Smart
High Forecast before Power Smart Low Forecast before Power Smart
54 563
856 54, 278
55, 375 55, 904
56, 180 912
859
54,447 54, 975 53, 929 928
55,442
Energy Requirements with Power Smart (Note 2):
Reference Load Forecast with Power Smart
High Forecast with Power Smart Low Forecast with Power Smart
Reduction in Energy Requirements due to Power Smart
54, 282 574 997 280
805 534 065 375
Supply
Heritage Resources:
Heritage Hydro (Note 3)
958
45,432
102
253
Heritage Thermal (Note 4) Market Purchases (Note 4)
4930
979
2316
47,850
1506
47,800
Total Heritage Resources
Committed New Resource Smart (Note 5) Purchases (Note 6): Energy Purchase Agreements Contracted before F2001 2000 Expression of Interest for Green Energy 2001 Green Energy Call 2002 Customer Based Generation 2002 Green Power Generation Planned New Resource Smart (Note 7) Vancouver Island Call for Tender (Note 8)
804
197 195
655 149 510 264
938 149 588 266
Total Purchases
230
54, 209
(354)
592
54, 442
994
54, 794
386)
Total Supply
Energy Balance: Supply less Forecast Demand before Power Smart
EnerQY Balance Based on Hiah Forecast
(933)
Enerav Balance Based on Low Forecast
(647) (69)
(73)
(1,462) (417)
(5)
118 (648
(11)
Energy Balance: Supply less Reference Forecast with Power Smart (Note 9)
Enerov Balance Based on Hiah Forecast
EnerQY Balance Based on Low Forecast
(365)
212
(533) 513
(740 729
Independent Power Producers Association of BC Information Request No. 1. 55. 1 Dated: 2 March 2004
BC H dro Res onse REVISION 1, 7
Page
Ma 2004
British Columbia Hydro & Power Authority Revenue Requirements lication 2004/05 and 2005/06
Notes:
(1) Energy load forecast is total integrated system gross requirement which includes losses but excludes load in the non- integrated areas (2) Energy savings achieved by Power Smart prior to F2004 are included in the Forecast Before Power Smart (3) Net adjusted Hydro (4) Most cost effective of Market Purchases and/or Heritage Thermal. Fort Nelson is not included in this table as it is not part of the integrated system. (5) These are projects that have financial approval. Totals are cumulative starting in F2004. (6) 2000 and 2001 Green Call and 2002 Customer Based Generation Call: some are in-service; most are under development (7) These are projects that are planned but need financial approval. Totals are cumulative starting in F2004. (8) Minimum is 1200 GWh and maximum is 2100 GWh (9) Minor differences due to: F2004 Reconcilng of generation load data, F2005/F2006 cancellation of 2 smalllPP projects (Revelstoke , McKelvie) Some columns may not add due to rounding High and Low load forecast are not available monthly Monthly Load forecast are from Oct Load Forecast (10) The perceived energy imbalance between April 2004 and October 2004 is primarily due to the timing difference between when load is consumed and when it is billed
Independent Power Producers Association of BC Information Request No. 1.55.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
55.0
Reference: 1.55.2
Application, Volume 1, Chapter 4, p.27 (Table 4-11)
For the assets classified under heritage resources (heritage hydro, heritage thermal, market purchases), please provide a further breakdown illustrating the resource supply for High-Load Hours (HLH) and Low-Load Hours (LLH). Provide BC Hydro’s definition of HLH and LLH.
RESPONSE: For longer forecasting purposes, such as the Application, BC Hydro does not currently model the generation from the Heritage Resources on HLH/LLH basis. All market purchases are assumed to be priced at LLH. HLH are defined as the hours ending 7am to 10pm on Monday to Saturday except for NERC defined holidays. LLH are defined as all other hours.
Independent Power Producers Association of BC Information Request No. 1.55.3 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
55.0
Reference: 1.55.3
Application, Volume 1, Chapter 4, p.27 (Table 4-11)
Please explain why “market purchases” should be deemed as a heritage resource.
RESPONSE: Under the Heritage Contract attached as Appendix A to Special Direction No. HC2, BC Hydro can choose to supply Heritage Energy from market purchases.
Independent Power Producers Association of BC Information Request No. 1.55.4 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
55.0
Reference: 1.55.4
Application, Volume 1, Chapter 4, p.27 (Table 4-11)
Please provide a sensitivity analysis of the monthly energy balances to the assumption of average water inflows for F2005 and F2006. Please re-calculate the monthly energy balances assuming water inflows are +/- 10%, +/-20% of average water inflows.
RESPONSE: BC Hydro models sensitivities to inflows by selecting historical weather sequences (by year) representing the targeted inflows. The inflow sequences used in the October study range from 1973 to 2003. The weather years that result in system inflows that are approximately +20%, +10% and -11% have been identified as 1997-1998, 1991-1992 and 1993-1994, respectively. A -20% inflow year is not a historical sequence in the modelling dataset. As -11% is the lowest inflow sequence, it has been included in the results. The results reflect the following assumptions: • Only the Peace River system and small hydro plants were modelled. BC Hydro inputs the Columbia and Arrow River systems on a deterministic basis for forecasting purposes. Each fiscal year was modelled for the targeted inflow year. Since the inflow years are sequential, the year prior to or after each fiscal year is modelled by the targeted inflow year +/-1, respectively. As the starting reservoir levels affect the outcome, F2005 and F2006 will have different results under the same inflow conditions regardless of other factors. Ending trade account balances were held constant.
•
• •
The table below shows the monthly energy balances under the stated inflow sequences
Independent Power Producers Association of BC Information Request No. 1.55.4 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 2
Inflows +21% Weather Sequence 1997-1998 Apr-04 Forecast 3,745 0 39 18 3,803 Apr-05 Forecast Hydro Electricity (Surplus Sales) Thermal Resources Exchange Net TOTAL 3,857 (79) 12 53 3,843 May-04 Forecast 3,682 0 2 102 3,786 May-05 Forecast 3,555 (79) 2 165 3,643 Jun-04 Forecast 3,385 0 2 171 3,558 Jun-05 Forecast 3,498 (299) 2 214 3,414 Jul-04 Forecast 3,732 (548) 18 178 3,380 Jul-05 Forecast 4,091 (903) 5 209 3,402 Aug-04 Forecast 3,896 (587) 25 138 3,472 Aug-05 Forecast 4,327 (968) 4 135 3,498 Sep-04 Forecast 3,711 (418) 4 112 3,409 Sep-05 Forecast 3,913 (578) 4 97 3,435 Oct-04 Forecast 4,154 (48) 2 (187) 3,921 Oct-05 Forecast 4,235 (99) 2 (196) 3,941 Nov-04 Forecast 4,273 (48) 2 62 4,289 Nov-05 Forecast 4,339 (79) 2 47 4,309 Dec-04 Forecast 4,956 (313) 2 39 4,684 Dec-05 Forecast 5,143 (472) 2 29 4,702 Jan-05 Forecast 4,815 0 2 (36) 4,781 Jan-06 Forecast 5,036 (180) 2 (45) 4,813 Feb-05 Forecast 4,331 0 2 (18) 4,315 Feb-06 Forecast 4,348 0 2 (25) 4,325 Mar-05 Forecast 4,467 0 2 (19) 4,450 Mar-06 Forecast 4,495 0 2 (23) 4,473 Total Forecast 49,148 (1,961) 102 561 47,850 Total Forecast 50,835 (3,736) 41 660 47,800
SOURCE OF SUPPLY (GW.h) Hydro Electricity (Surplus Sales) Thermal Resources Exchange Net TOTAL
Inflows +10% Weather Sequence 1991-1992 Apr-04 Forecast 3,391 354 39 18 3,803 Apr-05 Forecast Hydro Electricity Purchases Thermal Resources Exchange Net TOTAL 3,708 70 12 53 3,843 May-04 Forecast 3,235 448 2 102 3,786 May-05 Forecast 3,376 100 2 165 3,643 Jun-04 Forecast 2,827 558 2 171 3,558 Jun-05 Forecast 2,533 665 2 214 3,414 Jul-04 Forecast 3,136 48 18 178 3,380 Jul-05 Forecast 3,188 0 5 209 3,402 Aug-04 Forecast 3,255 54 25 138 3,472 Aug-05 Forecast 3,359 0 4 135 3,498 Sep-04 Forecast 3,293 0 4 112 3,409 Sep-05 Forecast 3,182 153 4 97 3,435 Oct-04 Forecast 4,006 100 2 (187) 3,921 Oct-05 Forecast 4,120 15 2 (196) 3,941 Nov-04 Forecast 4,156 69 2 62 4,289 Nov-05 Forecast 4,260 0 2 47 4,309 Dec-04 Forecast 4,643 0 2 39 4,684 Dec-05 Forecast 4,671 0 2 29 4,702 Jan-05 Forecast 4,783 32 2 (36) 4,781 Jan-06 Forecast 4,856 0 2 (45) 4,813 Feb-05 Forecast 4,311 19 2 (18) 4,315 Feb-06 Forecast 4,287 61 2 (25) 4,325 Mar-05 Forecast 4,360 107 2 (19) 4,450 Mar-06 Forecast 4,270 225 2 (23) 4,473 Total Forecast 45,396 1,791 102 561 47,850 Total Forecast 45,811 1,288 41 660 47,800
SOURCE OF SUPPLY (GW.h) Hydro Electricity Purchases Thermal Resources Exchange Net TOTAL
Inflows -11% Weather Sequence 1993-1994 Apr-04 Forecast 3,364 381 39 18 3,803 Apr-05 Forecast Hydro Electricity Purchases Thermal Resources Exchange Net TOTAL 3,730 48 12 53 3,843 May-04 Forecast 3,666 16 2 102 3,786 May-05 Forecast 3,476 0 2 165 3,643 Jun-04 Forecast 2,888 498 2 171 3,558 Jun-05 Forecast 3,169 29 2 214 3,414 Jul-04 Forecast 2,817 367 18 178 3,380 Jul-05 Forecast 3,188 0 5 209 3,402 Aug-04 Forecast 3,309 0 25 138 3,472 Aug-05 Forecast 3,359 0 4 135 3,498 Sep-04 Forecast 3,260 32 4 112 3,409 Sep-05 Forecast 3,318 17 4 97 3,435 Oct-04 Forecast 3,776 331 2 (187) 3,921 Oct-05 Forecast 4,136 0 2 (196) 3,941 Nov-04 Forecast 3,700 525 2 62 4,289 Nov-05 Forecast 3,881 379 2 47 4,309 Dec-04 Forecast 4,584 60 2 39 4,684 Dec-05 Forecast 4,532 139 2 29 4,702 Jan-05 Forecast 4,780 35 2 (36) 4,781 Jan-06 Forecast 4,735 121 2 (45) 4,813 Feb-05 Forecast 3,925 405 2 (18) 4,315 Feb-06 Forecast 3,534 814 2 (25) 4,325 Mar-05 Forecast 4,170 297 2 (19) 4,450 Mar-06 Forecast 4,083 412 2 (23) 4,473 Total Forecast 44,239 2,948 102 561 47,850 Total Forecast 45,140 1,959 41 660 47,800
SOURCE OF SUPPLY (GW.h) Hydro Electricity Purchases Thermal Resources Exchange Net TOTAL
In general, any reduction in system inflow below the average value will be mitigated partly by an additional system storage draft and partly by increased market purchases. System reservoir levels are currently fairly low and are projected to remain fairly low throughout F2005 and F2006. This diminishes the ability of system storage to participate in mitigation for low inflows. Therefore, while there may be some additional draft of system storage, additional market purchases will provide the primary mitigation for low inflows. Conversely, any increase in system inflow above the average value will result in a combination of increased storage refill and reduced market purchases. Currently, with low system storage levels, it is expected that higher-than-average inflows would be used primarily to refill system storage, with a smaller impact on market purchases.
Independent Power Producers Association of BC Information Request No. 1.56.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
56.0
Reference: 1.56.1
Application, Volume 1, Chapter 4, p.27 (Table 4-11)
Please confirm that Appendix F and the assumptions contained therein are the basis for the load forecast estimates in Table 4-11. If not, please provide the forecast of the following economic variables contributing tho the load forecast in Table 4-11: real GDP growth, inand out-migration patterns, population growth, housing starts and employment.
RESPONSE: Yes, Tables A7.1 to A7.6 in Appendix F are the basis for the load forecast estimates contained in Chapter 4, Page 4-27, Table 4-11.
Independent Power Producers Association of BC Information Request No. 1.56.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
56.0
Reference: 1.56.2
Application, Volume 1, Chapter 4, p.27 (Table 4-11)
Please provide a table reconciling Table 4-11 and the load forecasts of Appendix F. Please explain the differences.
RESPONSE: The load forecasts shown in Chapter 4, Page 4-27, Table 4-11 represent the forecasts of the Total Integrated System Gross Requirements Before Power Smart, With Power Smart and High and Low Forecasts Before and With Power Smart from F2004 to F2013. The load forecasts in Table 4-11 are the same forecasts in Appendix F, Table A7.1 to Table A7.6 under the header “Integrated System Total Gross Requirements (GW.h)”. Any minor differences that exist between the load forecasts in some years are due to rounding. The table below reconciles the load forecasts in Chapter 4, Table 4-11 and the tables of load forecasts in Appendix F, Tables A7.1 to A7.6. Reconciliation of Load Forecast in Table 4-11 and Appendix F Forecasts in Table 4-11 Tables of Load Forecasts in Appendix F Reference Load Forecast Before Power Smart High Forecast before Power Smart Table Low Forecast before Power Smart Reference Load Forecasts with Power Smart High Forecast with Power Smart Table Low Forecast with Power Smart Same as the Forecast of Integrated System Total Gross Requirements in Table A7.1. Same as the Forecast of Integrated System Total Gross Requirements in Table A7.3. Same as the Forecast of Integrated System Total Gross Requirements in Table A7.4. Same as the Forecast of Integrated System Total Gross Requirements in Table A7.2. Same as the Forecast of Integrated System Total Gross Requirements in Table A7.5. Same as the Forecast of Integrated System Total Gross Requirements in Table A7.6.
Independent Power Producers Association of BC Information Request No. 1.57.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
57.0
Reference: 1.57.1
Application, Volume 1, Chapter 5, p. 8
The application states: “ Benchmarking studies conducted during this time concluded that BC Hydro Generation’s reinvestment in facilities was significantly lower than others’ investments in comparable facilities.”
RESPONSE: The question is incomplete.
Independent Power Producers Association of BC Information Request No. 1.57.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
57.0
Reference: 1.57.2
Application, Volume 1, Chapter 5, p. 8
For all projects listed in Table 11-4 as “Growth” projects, please provide copies of the benchmarking studies, or like, conducted to determine that BC Hydro Generation’s reinvestment was significantly lower than other investments.
RESPONSE: Haddon Jackson Associates benchmarking on investment provides comparable data aggregated into the following categories of investment: generating systems; cooling systems; waterways and dams; buildings and grounds; and parks, fish and wildlife. It is not possible, therefore, to draw any conclusions from the benchmarking data on replacement of one component of the "generating system" (i.e., turbine runners at GM Shrum and Cheakamus generating stations). BC Hydro has benchmarked 12 hydroelectric facilities, including all large plants and a representative sample of strategic facilities, comprising 93% of total hydroelectric capacity. Aberfeldie has not been benchmarked. The unit cost of incremental energy from turbine upgrade projects at GM Shrum and Cheakamus generating stations is significantly less than the cost of energy from IPPs. Similarly, BC Hydro will add new capacity at Aberfeldie only if the cost is less than the cost of energy from IPPs.
Independent Power Producers Association of BC Information Request No. 1.58.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
58.0
Reference: 1.58.1
Application, Volume 1, Chapter 5, p. 9
Please explain the categorization of capital expenditures into “sustaining” and “growth”, as the reference to Chapter 2 is unclear.
RESPONSE: Growth capital expenditures include all Resource Smart expenditures. Please see Chapter 5, Section 6.3 for further details on these expenditures. All remaining capital expenditures are considered sustaining. Please also see BC Hydro’s response to BCUC IR #1.6.17(a) and the attachment “Business Planning Guidelines F2005 and F2006” pages 9-10 of BC Hydro’s response to BCUC IR # 1.75.4.
Independent Power Producers Association of BC Information Request No. 1.58.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
58.0
Reference: 1.58.2
Application, Volume 1, Chapter 5, p. 9
Provide the details in respect of “growth” projects for the F2003 to F2008 period: project description, capital expenditures, capacity addition, levelized unit cost.
RESPONSE: Details of the capital expenditures categorized as growth in Chapter 5, Section 2.3.1 are shown in the table below.
Independent Power Producers Association of BC Information Request No. 1.58.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 2
Planned Resource Smart – Turbine Upgrades Location
Expected Planned in Incremental Incremental Amounts Unit Value Unit Cost of Project Life Service Date Energy in Rated per F2005 of Incremental - Years GWh per Capacity in Capital Plan Incremental Energy ($ Annum MW (in millions) Capacity ($ per MWh) per kWYear) Ruskin Turbine Lower 50 Sept. 2006 16 0 $4.8 N/A 24.5 Upgrade Mainland Sept. 2007 WAH Turbine Upgrade Lower 50 Sept. 2007 10 0 2.0 N/A 18.5 Mainland GMS Turbine Upgrade Interior 50 Oct. 2006 125 0 49.3 N/A 28.6 - Units 1 to 5 Oct. 2010 GMS Unit 8 Capacity Interior 50 Oct. 2006 0 30 4.3 12 N/A Increase MCA Turbine Upgrade Interior 50 Sept. 2010 93 8 26.2 N/A 25.1 - Units 1 to 2 Sept. 2001 SEV Turbine Upgrade - Interior 50 Apr. 2007 81 0 18.2 N/A 18.7 Units 1 to 3 Apr. 2009 ASH Turbine Uprate 50 Sept. 2006 26 6 8.0 N/A 25.2 Vancouve r Island JHT Turbine Upgrade 50 Sept. 2006 36 7 9.2 N/A 21.1 Units 1 to 6 Sept. 2008 Vancouve r Island SCATurbine Upgrade 50 Sept. 2006 11 0 3.6 N/A 27.0 Units 1 and 2 Sept. 2007 Vancouve r Island Total 398 51 $125.6 24.4
Independent Power Producers Association of BC Information Request No. 1.59.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
59.0
Reference: 1.59.1
Application, Volume 1, Chapter 5, p. 15
Please provide the historical and targeted “unit cost of production” separately for the Burrard Generation Station. Include the targeted capacity factor.
RESPONSE:
Actual F2003 $17.4 14.2 Forecast F2004 $16.8 13.6 Plan F2005 $17.9 12.4 Plan F2006 $13.8 12.5
($ millions) Cost of Energy Operating, Maintenance, General and Administration Costs Asset Related Expenses Depreciation Taxes and Grants Finance Costs1 Return on Equity1 Less:Miscellaneous Revenues Revenue Requirement Generation Supply - Burrard (in GWh's) Unit Cost of Production ($ per MWh) Capacity Factor2
11.8 1.5 9.2 8.5 (1.3) $61.3 110 $557.3 1%
16.1 1.5 9.7 8.7 (1.3) $65.1 91 $715.4 2%
24.4 1.5 8.4 7.9 (1.6) $70.9 102 $695.1 3%
21.8 1.5 7.8 7.0 (1.5) $62.9 41 $1,534.1 1%
Note 1: Finance Costs and Return on Equity have been allocated to Burrard based upon net book value at the end of each fiscal year. Note 2: Assumes starting in F2004, only three units of Burrard Generating Station are used for energy generation.
Burrard Generating Station is currently being utilized for dependable capacity and is providing voltage support. Dispatch of Burrard Generating Station for energy is available, but is expected to be insignificant due to the high cost of dispatch over the next two to three years relative to the cost of purchasing energy from the market. The high cost of production and low capacity factors shown in the table above for Burrard Generating Station are reflective of a facility that is not being used as an energy resource.
Independent Power Producers Association of BC Information Request No. 1.60.1 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
60.0
Reference: 1.60.1
Application, Volume 1, Chapter 5, p. 25
Please provide a copy of the Asset Plan for Burrard Generation Station.
RESPONSE: The Burrard Generating Station F2005 Asset Plan is attached.
FACILITY ASSET PLAN
Fiscal 2004/05
BURRARD GENERATING STATION
Generation
Facility Asset Plan
Burrard Generating Station
1
BUSINESS CONTEXT................................................................................................................. 3 1.1 PURPOSE .................................................................................................................................3 1.2 CURRENT STATUS ......................................................................................................................3 1.3 BURRARD’S C URRENT O PERATING PLAN .......................................................................................3
2
FACILITY OVERVIEW................................................................................................................. 6 2.1 2.2 2.3 2.4 2.5 GENERAL D ESCRIPTION ..............................................................................................................6 PRODUCTS & SERVICES ..............................................................................................................7 SUMMARY OF N ET B OOK VALUE OF ASSETS ...................................................................................7 PLANT PERFORMANCE SUMMARY .................................................................................................8 SUSTAINABILITY & COMMUNITY SUMMARY .....................................................................................9
3
F2005/F2006 OPERATING PLAN .............................................................................................. 10 3.1 OPERATING STRATEGY ............................................................................................................. 10 3.2 FACILITY MAINTENANCE AND RE- INVESTMENT STRATEGY ................................................................. 10 3.2.1 Maintenance................................................................................................................... 12 3.2.2 Capital Plan.................................................................................................................... 13 3.3 R ISKS .................................................................................................................................... 14 3.4 PERFORMANCE........................................................................................................................ 15 3.4.1 Financial Efficiency......................................................................................................... 15 3.4.2 Operational Efficiency..................................................................................................... 15 3.4.3 Environmental Stewardship ............................................................................................. 15 3.4.4 Social & Community Contribution..................................................................................... 16
Page 2
Facility Asset Plan
Burrard Generating Station
1 BUSINESS CONTEXT
1.1 PURPOSE
This document is a compilation of key information related to the Burrard Generating Station (BGS). The Burrard Asset Plan takes a 1 to 2 year focus because of the uncertainties related to the long term options for the asset.
1.2 CURRENT STATUS
When the decisions were made to proceed with the Burrard Upgrade Project and to acquire firm gas transportation for Burrard, the gas and electricity market forecasts at the time were such that Burrard was expected to generate significant amounts of energy for the BC Hydro system. However, natural gas prices have increased significantly relative to energy prices and consequently, Burrard has generated approximately 100 GWh/yr in the last and current fiscal year. This low level of generation is expected to continue over the next two to three years because during this period it is forecast to be more economic to purchase energy from the market than to purchase natural gas to generate energy with Burrard. Burrard is currently relied on as a source of dependable capacity and firm energy for planning purposes. BC Hydro is conducting a high level resource planning exercise with the 2004 Integrated Electricity Plan (IEP), and the outcome is expected shortly. From Generation’s operating perspective, Burrard is currently not dispatched for energy, and Burrard’s primary role is to provide voltage support and standby capacity. Informed by the IEP and the outcome of the MLA Committee’s review, Generation expects to make a recommendation as to the future of Burrard by the end of F2005. Several actions were taken in F2004 to minimize costs at Burrard while not foreclosing any economic options until a decision is made as to its future. These actions include: • Shutting down the energy and capacity generating capability for Units 1, 2 and 3, and operating these units only in synchronous condense mode. These units are still being maintained to allow for the potential for future recall. As a consequence, staff positions were eliminated at Burrard and capital investment was limited; • Maintaining Burrard Units 4, 5, and 6 to remain capable of providing capacity and energy, if required (Unit 4 is also capable operating in synchronous condense mode) • Accelerating the depreciation of Burrard net book value to a period of 10 years.
1.3
BURRARD’S CURRENT OPERATING PLAN
The objective of Burrard’s current operating plan is to minimize costs of Burrard while maintaining future options until a decision is made as to its future. The operating plan provides for the following: • Units 1, 2, 3 in synchronous condense mode to provide VARs
Page 3
Facility Asset Plan
Burrard Generating Station
• • •
The option to recall Units 1, 2, and 3 for energy and capacity. This is required to be consistent with the requirements to meet the planning criteria. Units 4, 5, and 6 on standby capacity; Units 4, 5, and 6 capable of generating energy if required, although the O&M and sustaining capital would need to be re-evaluated.
Burrard is not expected to be significantly dispatched to generate energy in the next two years. However, Burrard will be required to continue to provide voltage support to the transmission system, and may be required to provide winter capacity. Burrard can generate VARs when it is operating in synchronous condense mode, and to a lesser extent when it is generating energy. The VARs generated by Burrard play a vital role to the BC Hydro system. Significant amounts of VARs are required to continue to allow for high power transfers from the Peace and Columbia system to help meet peak load, and also to allow for importing of energy during light load hours. BCTC has estimated that for the VAR capability to be replaced with static var compensators (SVCs), the lead time is up to 5 years. Therefore, Burrard needs at a minimum to continue to operate to provide VARs in the near term. The estimated costs for operating Burrard solely to only provide VARs are: • • • Facility O&M and G&A: $3 M/yr in F2005 Facility Capital: $3M/yr with the largest single cost component being continuation of the Asbestos Management Program “Sunk” or fixed costs – this includes depreciation on existing assets, the annual costs associated with the Burrard Bypass Agreement, allocated financing charges and allocated return on equity. These costs would continue regardless.
For Burrard to provide dependable capacity in addition to VARs, the following additional costs are required: • • Cost of Energy: purchases of gas to enable each of Units 4, 5, and 6 to be exercised for 2 days every 2 months. The cost of gas purchases is partially offset by the value of the energy Facility O&M and G&A: additional $9.4 M for a total of $12.4 M in F2005
Based on the key assumption that Burrard must continue to operate to generate VARs first and then incrementally to provide capacity as described above, the following table shows Burrard’s costs allocated between these two main products for F2005:
Page 4
Facility Asset Plan
Burrard Generating Station
F2005 Allocated Costs by Product
Energy Capacity Costs Gas Commodity Gas Transportation Operating Costs Taxes and Grants-in-Lieu Depreciation
Description To enable Burrard to provide dependable capacity
Units
VARs
Capacity
GWh MW
N/A N/A
102 456
Related to Energy above Fixed Cost Dependent on products Fixed Cost Fixed Cost Steam sales; costs are included in Gas Commodity Fixed Cost Fixed Cost Related to Energy above
$M $M $M $M $M
N/A $9.8 3.0 1.5 24.4
$8.1 N/A 9.4 N/A N/A
Other Revenue Finance Charges (allocated by NBV) Return on Equity (allocated by NBV) Total Costs Value of Energy Net Cost Unit Incremental Cost of Capacity
$M $M $M $M $M $M $/kW-yr
0 8.4 7.9 55.0 N/A 55.0 N/A
-1.6 N/A N/A 15.9 5.0 10.9 $23.9
The analysis for F2005 shows that incrementally, the unit cost of capacity is $23.9/kW-yr. Until new resources could be acquired, the only viable replacement alternative is a market capacity call option. The cost of the capacity call option would depend on several factors, but for planning purposes, Powerex has provided an estimate of $7.5/kW-yr. This is based on the assumption that BC Hydro only requires the capacity during the winter months November to February. When the comparison is made between the incremental cost of capacity from Burrard and a potential market call option, the analysis shows that it is likely more economic to supply the capacity from the market in the near term. The premium of $16.4/kW-yr over market for continuing Burrard in this operation could be attributed to the benefit of keeping plant available for recall. The value of recall needs to be examined in more detail. For Burrard to remain in this mode of operation, management needs reduce costs in order to be competitive with the market alternative.
Page 5
Facility Asset Plan
Burrard Generating Station
2 F ACILITY OVERVIEW
2.1 GENERAL DESCRIPTION
Burrard Generating Station (BGS) is located within the City of Port Moody in the Lower Mainland, about 18km from downtown Vancouver. It is a conventional, natural gas-fired, steam electric generating station consisting of six independent units each with a boiler, turbo-generator and steam condenser. Each unit has a condenser cooling water system that employs saltwater from Burrard Inlet. A de-mineralized water treatment plant fed from Buntzen Lake supplies the high quality water required for steam generation. The generating units were added in stages, the first unit went on-line in 1962 and the sixth was commissioned in 1975. Units 1 through 4 have been modified to operate either as generators or as synchronous condensers. For asset management purposes, it is classified as a “large” facility
Facility Summary Units Unit Unit Unit Unit Unit Unit MW MW GJ/MWh GJ/MWh GWh/yr BGS 1 2 3 4 5 6 – – – – – – 1965 1963 1962 1967 1968 1975
In-service Year
Category Capacity (net) – Units 1 to 6 Capacity (net) – Units 4 to 6 Heat Rate at Full Output Heat Rate at Minimum Output Last Year Energy Generation (F2003)
Large 913 456 10.16 11.62 110
Page 6
Facility Asset Plan
Burrard Generating Station
2.2 PRODUCTS & S ERVICES
Products & Services Fleet Services Capacity (net) Ancillary Transmission Services Voltage Support Synchronous Condense Black Start Energy Forecast Generation Firm Energy Capability (3 units @ 85% availability) Typical Useage (1) Base Load Load Factoring Swing AGC
(3) (4) (2)
Unit MW Y/N Y/N Y/N GWh GWh
F2005/F2006 456 Y for system Y N 102/41 3440
Y/N Y/N Y/N Y/N
Y Y N N --
External Services T&D Steam Sales Aquatic Studies Recreation
(1) (2) (3) (4)
$ 000 $ 000 ppl/y
~1500 15 100
Base Load units stay on line predominately. Load Factoring units’ output is increased in high load hours and decreased in light load hours. Swing Plant is used to meet increase or decrease in demand in steps throughout the day. AGC plant adjusts output continually to meet incremental demand change.
2.3 SUMMARY OF NET BOOK VALUE OF ASSETS
Burrard Asset Continuity Schedule ($millions) Net Book Value of Assets in Service March 31 2003 Unfinished Construction March 31, 2003 Contributions in Aid of Construction March 31, 2003 Forecast asset additions F2004 Forecast depreciation and amortization F2004 Net Asset Investment to March 31, 2004 $166 29 (7) 11 (16) $183
Page 7
Facility Asset Plan
Burrard Generating Station
Financial Statistics (Forecast for March 31, 2004) Assets in Service Accumulated Depreciation Net Book Value
Units Millions Millions Millions
BGS $362 $179 $183
2.4 PLANT PERFORMANCE SUMMARY
The following table summarizes the reliability metrics for Burrard from F1998 to F2003. During this period of time, all the units were removed from service for various lengths of time because of the Burrard Upgrade project. This would reflect in decreased availability. In addition if units had a forced outage and was not forecasted to be required, the choice would be made to defer fixing the unit and returning it to service. This would tend to increase the length of forced outages.
F1998 Actual 2.04 6.44 4.24 F1999 Actual 0.91 8.45 4.68 F2000 Actual 20.41 8.98 14.70 F2001 Actual 40.71 2.81 21.76 F2002 Actual 65.98 4.44 35.21 F2003 Actual 28.66 7.31 17.98
Forced Outage Factor (%) Units 1, 2, 3 (East side) Units 4, 5, 6 (West side) Plant Average
Number of Forced Outages Units 1, 2, 3 (East side) Units 4, 5, 6 (West side) Average Number of Forced Outages/Unit
F1998 Actual 1.67 3.67 2.67
F1999 Actual 1.67 6.00 3.83
F2000 Actual 1.00 5.00 3.00
F2001 Actual 3.33 2.00 2.67
F2002 Actual 3.00 4.00 3.50
F2003 Actual 2.67 3.33 3.00
Availability (%) Units 1, 2, 3 (East side) Units 4, 5, 6 (West side) Plant Average
F1998 Actual 75.49 58.75 67.12
F1999 Actual 81.54 77.92 79.73
F2000 Actual 56.83 69.85 63.34
F2001 Actual 44.96 77.52 61.24
F2002 Actual 30.45 73.42 51.93
F2003 Actual 68.59 58.56 63.58
Major planned outages associated with the Burrard Upgrade Projects on Units 4, 5, and 6 have included the following: • Unit 4 in F2003 (August to January) • Unit 5 in F2003 (May to October) • Unit 6 in F2002 (December – March)
Page 8
Facility Asset Plan
Burrard Generating Station
2.5 SUSTAINABILITY & C OMMUNITY SUMMARY
Initiatives to promote Public Consent: • Maintain ISO 14001 registration and communicate results. • Maintain BGS Emergency Response Plan • Co-operate with the movie industry by providing locations for filming. Modest revenues are received that exceed costs. • Future of Burrard annual Open House and School Tours requires review.
Page 9
Facility Asset Plan
Burrard Generating Station
3 F2005/F2006 OPERATING PLAN
3.1 OPERATING STRATEGY
The following is the current plan for Burrard based on the assumption that Burrard Units 1,2 and 3 will continue operating to provide voltage support but will be maintained to preserve the option of future recall. Units 4, 5, and 6 will continue to be used for standby capacity and to be available for energy generation if required. F2005 Strategy/Objectives: • Maintain staffing and competencies to operate and maintain plant at three units of capacity and three units of synchronous condense capability. • Preserve remaining generating units 1, 2 and 3, not required for capacity in F2005, in dry storage available for future recall • Manage plant operations to maintain full consent to operate. • When required by BC Hydro or Powerex, operate with all commercially available units, subject to the cooling water, air permits and voluntary curtailment provisions • Provide process steam to the adjacent Imperial Oil IOCO Terminal Facility. • Maintain ISO 14001 registration of the Burrard Environmental Management System (EMS). • Maintain the Burrard Emergency Response Plan (ERP). • Minimize spending pending the decision as the future of the facility is made later in F2005 F2005 Main Initiatives: • To maintain operator capability and ensure plant availability, each of units 4, 5, and 6 will be operated for two days every 2 months. This is required to ensure that Burrard is capable of providing dependable capacity • Asbestos Management Program work as determined by the Asbestos Action Plan. • Continue to supply contracted steam to the adjacent IOCO facility.
3.2
FACILITY MAINTENANCE AND RE-INVESTMENT STRATEGY
Based on the current operating plan, investment will be the minimum to meet the above requirements. The boiler, turbine, and condenser for Units 1, 2 and 3 are maintained in dry storage in order to preserve the units for future recall.
Page 10
Facility Asset Plan
Burrard Generating Station
Major Equipment
CNO Year 1965
EHR Rating
Last Overhaul
Expected Intervention Activity
Unit 01
Boiler Turbine Condenser Generator Excitation System Unit P&C Unit 02
F
F1999 F1999 N/A F2002
Current operating plan is for synchronous condense operation only for Units 1, 2, 3. No work planned for prime mover equipment. Currently in Dry Storage
1963
Boiler Turbine Condenser Generator Excitation System Unit P&C Unit 03
F
F2003 N/A F2004
Scheduled preventive maintenance Scheduled preventive maintenance Scheduled preventive maintenance Current operating plan is for synchronous condense operation only for Units 1, 2, 3. No work planned for prime mover equipment. Currently in Dry Storage Remaining life of 10,000 hours. Bearing failure & rotor shaft damage. Repairs are in-progress. Scheduled preventive maintenance Scheduled preventive maintenance Current operating plan is for synchronous condense operation only for Units 1, 2, 3. No work planned for prime mover equipment. Currently in Dry Storage Steam path inspection past due. Inspection required prior to generation. Scheduled preventive maintenance Scheduled preventive maintenance Scheduled preventive maintenance Current operating plan is for capacity only for Units 4, 5, 6. If energy products required, additional work such as boiler acid cleaning may be required. Scheduled preventive maintenance Remaining life of 15,000 hours. Scheduled preventive maintenance Scheduled preventive maintenance Scheduled preventive maintenance New Distributed Control System (DCS) commissioned.
1962
Boiler Turbine Condenser Generator Excitation System Unit P&C Unit 04 N/A P
1967
Boiler Turbine Condenser Generator Excitation System Unit P&C
F2002 N/A P 2003 F2004
Page 11
Facility Asset Plan
Burrard Generating Station
Major Equipment
CNO Year 1968
EHR Rating
Last Overhaul
Expected Intervention Activity
Unit 05
Boiler Turbine Condenser Generator Excitation System Unit P&C Unit 06 1975
F2002 N/A P 2003 F2004
Boiler Turbine Condenser Generator Excitation System Unit P&C Station Ammonia Plant Auxiliary Boiler 1961
N/A F 2003 F2004
Current operating plan is for capacity only for Units 4, 5, 6. If energy products required, additional work such as boiler acid cleaning may be required. Scheduled preventive maintenance Remaining life of 15,000 hours. Scheduled preventive maintenance Scheduled preventive maintenance Scheduled preventive maintenance New Distributed Control System (DCS) commissioned. Current operating plan is for capacity only for Units 4, 5, 6. If energy products required, additional work such as boiler acid cleaning may be required. Scheduled preventive maintenance Remaining life of 96,000 hours. Scheduled preventive maintenance Scheduled preventive maintenance Scheduled preventive maintenance New Distributed Control System (DCS) commissioned. Scheduled preventive maintenance Scheduled preventive maintenance, boiler retube. Auxiliary boiler supplies steam under contract to IOCO Terminal. Scheduled preventive maintenance Corrosion control system rehabilitation work. Scheduled preventive maintenance Scheduled preventive maintenance
1996 1961
F2004
DC Station Service Saltwater Cooling System Transformers Water Treatment Plant
2003
3.2.1 MAINTENANCE
No major maintenance is planned for F2005. Due to low generation in F2004, low generation planned for fiscal 2005 and 2006 and major work completed in prior fiscal years, maintenance is limited to routine work.
Page 12
Facility Asset Plan
Burrard Generating Station
Workforce: • Maintain levels of staffing necessary to perform Preventive Maintenance, Condition Based and Corrective Maintenance. Use contractors for major overhauls and major repairs when required • Use maintenance engineers to optimise maintenance intervals and thereby reduce maintenance backlog to acceptable levels. • Develop and implement Personal Development Plans for all staff, annually. • Optimise workforce for current operations plan that focuses on provision of capacity products from Units 4, 5 and 6 and voltage support / synchronous condense products from Units 1, 2 and 3. The following table summarizes BGS’s actual maintenance costs for F2003 and forecasts costs for F2004 to F2006:
($ 000) Total Maintenance Costs Generation (GWh) – Oct 03 Plan1 F2003 Actual $6,763 110 F2004 Forecast $5,294 91 F2005 Plan $5,553 102 F2006 Plan $5,666 41
The operating plan is to minimise expenditures required to deliver standby capacity and voltage support. As a result the annual Plan amounts are relatively small and any unplanned expenditures will significantly impact the maintenance shown above.
3.2.2 CAPITAL PLAN
Investment will be minimised consistent with the current operating plan. Conversion of Units 5 and 6 to synchronous condense capability has been deferred, as has the purchase of a second synchronous condense start-up package. In F2005, the only significant capital expenditure is the continuation of the Asbestos Management Program including patch, repair and removal. The following table shows capital spent at the facility for F2003, forecast to be spent for F2004 and planned expenditures for F2005 to F2006.
($ millions) Burrard Upgrade Project BGS GS Asbestos Management Others Total
F2003 Actual $15.4 0.9 1.7 $20.5
F2004 Forecast $8.3 0.9 2.2 $11.4
F2005 Plan $0 1.0 1.5 $3.0
F2006 Plan $0 1.3 1.7 $3.0
1
Jan 04 update: Burrard generating 182 GWh in F2005 and 77 GWh in F2006. The increase is based on improved estimates of the operating plan to maintain operator capability and plant availability
Page 13
Facility Asset Plan
Burrard Generating Station
The expenditures for F2005 and F2006 are required regardless of the outcome of the Burrard options review. That is, the capital plan amounts will still be required even if the existing units are shutdown for energy and capacity.
3.3 RISKS
Risk
Continuing uncertainty as to the future of Burrard Continued availability of the skilled, specialised workforce, due to the high average age of Burrard staff and the uncertain future of the plant. Asbestos risk. Oil spill containment.
Mitigation
Minimise expenditures while attempting to keep future options open. Staffing strategies to maintain a workforce that matches plant requirements. Consistent and frequent messages regarding the current operating plan for the plant. Managed through Burrard Asbestos Management Program. This risk is managed by Thermal Generation with assistance from Engineering Services using an approach similar to the code developed by the Oil Spill Containment program. This risk is managed by Thermal Generation with assistance from Engineering Services. This risk is managed by Thermal Generation with engineering assistance from Engineering Services using an approach similar to that developed by the Fire Risk Reduction program. Stay abreast of regulatory agency and industry changes and trends.
Seismic Risk Fire Risk
Risk from future changes in regulations (e.g. WCB regulations, permitting) or the results of future audit (ISO audits) may require action. Ability to recall units placed in longterm storage. Site security.
Maintain core staff capabilities and ensure appropriate storage of units. A site security project is in progress to address issues.
Page 14
Facility Asset Plan
Burrard Generating Station
3.4 PERFORMANCE
3.4.1 FINANCIAL EFFICIENCY
Area of Focus O&M and G&A Capital Measure $M $M
F2003 Actual
$ 14.2 $20.5
F2004 Forecast
$13.6 $11.4
F2005 Plan
$ 12.4 $ 3.0
F2006 Plan
$12.5 $3.0
The O&M, G&A, and capital costs shown in the above table for F2005 and F2006 reflect the current plan to operate Burrard Units 1-3 on synchronous condense mode, Units 4-6 for standby capacity, while maintaining the option for the future recall of units 1-3. These costs are subject to change if the operating plan for Burrard changes significantly.
3.4.2 OPERATIONAL EFFICIENCY
Area of Focus Safety Number of incidents Lost time Plant Performance Availability – Units 4, 5, 6 % time VARs delivered % % 58.56 % 100% To come 100% 85% 100% 85% 100% # Hours 4 N/A 0 0 0 0 0 0
Measure
F2003 Actual
F2004 Forecast
F2005 Plan
F2006 Plan
3.4.3 ENVIRONMENTAL STEWARDSHIP
Area of Focus Environmental Management System Permit compliance – Air Permit compliance – Saltwater cooling water Permit compliance – Saltwater cooling water Permit compliance – Chlorine
Measure
Registration / Maintained Air Emissions Temperature Volume Chlorine
F2003 Actual
Maintain Compliance Compliance Compliance Compliance
F2004 Forecast
Maintain Compliance Compliance Compliance Compliance
F2005 Plan
Maintain Compliance Compliance Compliance Compliance
F2006 Plan
Maintain Compliance Compliance Compliance Compliance
Page 15
Facility Asset Plan
Burrard Generating Station
The Burrard EMS was re-registered in F2002 and the surveillance audit in December 2003 was positive; minor non-conformance issues are being managed. There were no air quality events that would have triggered our voluntary de-rating procedure.
3.4.4 SOCIAL & C OMMUNITY CONTRIBUTION
F2003 Actual
0
Area of Focus First Nations Grievances
Measure
# New Public Safety Management Plan
F2004 Forecast
0 Published Plan
F2005 Plan
0 Maintain Plan
F2006 Plan
0 Maintain Plan
Recreation
There have been no public safety incidents in recent years. A Public Safety Management Plan is in draft for completion in spring 2004. Risks of wild fires were successfully managed in cooperation with GVRD Parks and recreational user groups during the summer of 2003.
Page 16
Independent Power Producers Association of BC Information Request No. 1.60.2 Dated: 2 March 2004 BC Hydro Response issued 29 March 2004 British Columbia Hydro & Power Authority Revenue Requirements Application 2004/05 and 2005/06
Page 1
60.0
Reference: 1.60.2
Application, Volume 1, Chapter 5, p. 25
Please provide a list, on an individual generating unit basis, for all scheduled and unscheduled outages of the generating units at the Burrard Generating Station that exceed 2 days for the last 10 years.
RESPONSE: A list of Burrard Generating Station outages is provided on the enclosed CD-ROM. As discussed during the Heritage Contract hearings, certain Burrard outages could have been shortened, in some cases considerably, if there had been an economic or other incentive to operate the plant. Burrard Generating Station will typically only generate when the cost of electricity generated from the plant is less than the cost of market purchases. During times when market purchases are more economic than operating Burrard Generating Station, it is economic to delay repairs on any failed equipment until gas prices fall or electricity prices increase such that Burrard Generating Station is economic to operate. Thus, outages may be extended even though the underlying cause of failure is minor.
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01
State Code 15 12 21 12 12 12 15 12 12 12 12 12 12 25 25 12 12 21 12 24 12 12 12 12 12 12 25 25 12 15 12 12 15 12 15 12 15 15 12 12 12 12 12 25 24 21 21 21 21 24 21 12 25 12 25 25 12 12 12 12 12 12 12 12 12 12
Forced Outage Type
3
1
2 1 1 1 1
State Description Available but not Operating under a forced derating Operating under a forced derating Deferable Forced Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Sudden Forced Outage Operating under a forced derating Corrective Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Corrective Maintenance Outage Imediately Deferable Forced Outage Sudden Forced Outage Sudden Forced Outage Sudden Forced Outage Corrective Maintenance Outage Sudden Forced Outage Operating under a forced derating Preventive Maintenance Outage Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating
Sync Cond Code
1 1
Common Mode Capacity Outage During Code State 75 40 0 90 135 135 135 135 135 130 75 135 135 0 0 130 75 0 130 0 130 130 130 130 130 130 0 0 130 130 130 130 130 130 130 130 130 130 130 130 130 72 130 0 0 0 0 0 0 0 0 160 1 0 130 0 0 130 150 150 1 149 1 136 1 140 150 150 150 150
Start Date-Time 1993-04-01 08:00 1993-04-18 17:30 1993-04-21 05:30 1993-04-22 17:49 1993-05-16 07:22 1993-05-20 16:35 1993-05-21 21:31 1993-05-24 13:17 1993-06-08 08:24 1993-06-24 16:35 1993-07-13 08:00 1993-07-19 08:00 1993-08-12 07:45 1993-10-26 07:40 1994-04-03 22:10 1994-04-09 22:13 1994-04-11 15:10 1994-04-18 10:32 1994-04-22 23:40 1994-05-26 20:25 1994-05-28 05:40 1994-06-18 13:12 1994-07-24 00:27 1994-09-14 20:00 1994-09-24 13:00 1994-09-30 22:50 1994-11-14 14:22 1995-01-24 04:30 1995-02-01 06:15 1995-03-03 09:55 1995-03-08 11:30 1995-03-13 17:30 1995-03-24 11:10 1995-03-28 13:07 1995-06-10 09:00 1995-06-13 03:15 1995-06-22 16:30 1995-06-27 23:47 1995-07-05 20:50 1995-07-16 18:30 1995-07-20 09:45 1995-09-05 12:15 1995-09-08 09:50 1995-10-01 10:14 1996-05-06 15:45 1996-05-24 08:25 1996-07-17 23:21 1996-07-19 22:05 1996-08-01 19:17 1997-09-24 10:18 1997-11-05 16:48 1997-11-07 19:16 1998-01-19 08:00 1998-02-01 00:01 1998-02-10 08:00 1998-05-01 00:01 1998-07-31 19:45 1998-08-05 06:00 1998-08-08 06:00 1998-08-16 06:00 1998-08-19 06:00 1998-08-21 06:00 1998-08-24 06:00 1998-09-01 07:00 1998-09-22 12:00 1998-09-24 00:00
Finish Date-Time 1993-04-14 16:00 1993-04-19 17:40 1993-04-22 17:49 1993-04-30 13:45 1993-05-20 01:40 1993-05-21 21:31 1993-05-24 13:17 1993-05-25 21:00 1993-06-15 02:00 1993-07-13 08:00 1993-07-19 08:00 1993-07-21 21:10 1993-10-26 07:40 1993-10-30 00:30 1994-04-09 22:13 1994-04-11 15:10 1994-04-18 10:32 1994-04-22 23:40 1994-05-26 20:25 1994-05-28 05:40 1994-06-18 12:27 1994-07-23 08:25 1994-09-14 18:25 1994-09-24 09:30 1994-09-30 19:00 1994-11-14 14:22 1994-11-21 15:05 1995-02-01 06:15 1995-03-03 09:55 1995-03-08 11:30 1995-03-13 07:00 1995-03-24 11:10 1995-03-28 13:07 1995-06-10 09:00 1995-06-13 03:15 1995-06-22 16:30 1995-06-27 00:01 1995-07-05 20:50 1995-07-16 18:05 1995-07-20 09:15 1995-09-05 12:15 1995-09-08 09:50 1995-10-01 10:14 1995-10-28 20:59 1996-05-08 17:50 1996-07-09 22:00 1996-07-19 16:05 1996-07-23 20:22 1996-11-03 17:05 1997-09-26 16:55 1997-11-07 19:16 1998-01-19 08:00 1998-02-01 00:01 1998-02-10 08:00 1998-04-01 00:01 1998-07-31 19:45 1998-08-02 23:53 1998-08-07 06:00 1998-08-16 06:00 1998-08-18 01:25 1998-08-21 06:00 1998-08-23 06:00 1998-08-29 05:00 1998-09-22 08:20 1998-09-23 16:35 1998-10-05 04:00
Outage Code 43400 42120 42100 43200 43100 43100 43100 43100 43100 43100 43200 43100 43100 99999 99999 43100 43200 42200 43100 31570 43100 43100 43100 43100 43100 43100 99999 04200 43100 43100 43100 43100 43100 43100 43100 43100 43100 43100 43100 43100 43100 31000 43100 04200 41170 42300 64200 42111 42112 43100 52130 43100 71190 43100 39000 39000 31570 43100 43100 07210 07210 07210 43100 43100 43100 43100
Outage Component Amp. Outage Code Type Comments F UNIT ON 6 HR STD/BY A B F STATOR GROUND FAULT 59N3 F BALANCING ALT & MEGGERING UNIT RESTRICTED 90 MW A B L UNIT RESTRICTED TO 135 MW L UNIT RESTRICTED TO 135 MW L UNIT ON 3 HR STD/BY LOAD L UNIT RESTRICTED TO 135 MW UNIT RESTRICTED TO 135 M. UNIT RESTRICTED TO 130 M. UNIT RESTRICTED TO 75 MW L ALL HP HTRS OOS L UNIT RESTRICTED 135 MW NO M CONVERSION TO SYNC COND M M UNIT SHUTDOWN FOR CONVERS L UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 75 MW F WO.#919803 GROUND FAULT A UNIT RESTRICTED TO 130 MW M SAFETY VALVE MODIFICATION UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 130 MW UNIT RESTRICTED TO 130 MW UNIT BEING CONVERTED FOR P UNIT CONVERSION FROM SYNC L NO HP HTRS (OUT FOR REPAI L UNIT SHUT DOWN ON 6 HOUR L NO HP HTRS (OUT FOR REPAI L NO HP HTRS (OUT FOR REPAI L UNIT SHUT DOWN ON 6 HOUR L NO HP HTRS (OUT FOR REPAI UNIT IS ON 6 HOUR STD/BY L NO HP HTRS. (OUT FOR REPA UNIT IS ON 6 HOUR STD/BY UNIT IS ON 6 HOUR STD/BY UNIT IN SERVICE, BUT REST L UNIT IS IN SERVICE, BUT R L UNIT IS IN SERVICE, RESTR A BOILER HAS HIGH SILICA LE BUT RESTRICTED TO 130 MW P UNIT CONVERSION TO SYNCHR I TO REMOVE THE SPADE FROM L BOTTOM EAST H2 COOLER LEA F UNIT TRIP 86-B RELAY, NO F WATER LEAKAGE FROM COOLER LEAKAGE AT HYDROGEN SEALS All HP heaters o.o.s.; Sy Forced Outage; Unit Aux. All HP heaters o.o.s.; Un Sync. Condenser operation Sync. Condenser operation NOx reduction equip inst. Planned Outage; SCR insta Forced derate; Safety val Forced derate; 4/5 hp hea Forced derate; 4/5 hp hea E Forced derate; CW permit E Forced derate; CW permit E Forced derate; CW permit Forced derate; 4/5 hp hea Forced derate; 4/5 hp hea Forced derate; 4/5 hp hea Forced derate; 4/5 hp hea
Year 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1996 1996 1996 1996 1996 1997 1997 1997 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998
Duration in Hours 320.00 24.17 36.32 187.93 90.30 28.93 63.77 31.72 161.60 447.42 144.00 61.17 1799.92 88.83 144.05 40.95 163.37 109.13 812.75 33.25 510.78 835.22 1265.97 229.50 150.00 1071.53 168.72 193.75 723.67 121.58 115.50 257.67 97.95 1771.88 66.25 229.25 103.52 189.05 261.25 86.75 1130.50 69.58 552.40 658.75 50.08 1117.58 40.73 94.28 2253.80 54.62 50.47 1740.73 304.02 223.98 1192.02 2203.73 52.13 48.00 192.00 43.42 48.00 48.00 119.00 505.33 28.58 268.00
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 01 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02
State Code 12 12 12 15 24 25 23 12 12 12 12 25 25 21 21 21 21 21
Forced Outage Type
4 2 4 2 4
State Description Operating under a forced derating Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Corrective Maintenance Outage Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Starting Failure Imediately Deferable Forced Outage Starting Failure Imediately Deferable Forced Outage Starting Failure
Sync Cond Code
25 25 25 25 25 24 25 21 21 12 12 25 21 24 21 25 12 12 24 24 24 24 24 24 24 25 24 25 25 24 25 25 25 15 25 13 25 12 24 21 15 21 4 1
Preventive Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Starting Failure Sudden Forced Outage Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Deferable Forced Outage Corrective Maintenance Outage Sudden Forced Outage Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Available but not Operating under a forced derating Preventive Maintenance Outage Operating under a schedualed derating Preventive Maintenance Outage Operating under a forced derating Corrective Maintenance Outage Sudden Forced Outage Available but not Operating under a forced derating Starting Failure
3 1
1
1 4
25
Preventive Maintenance Outage
Common Mode Capacity Outage During Code State 135 150 150 150 0 0 0 150 155 155 155 1 0 0 0 0 0 0 0 0 0 0 0 0 1 0 1 0 1 0 0 0 0 0 81 100 0 0 0 0 0 130 75 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 40 0 160 0 150 0 0 150 0 0 0 0
Start Date-Time 1998-10-05 04:00 1998-10-09 12:50 1998-10-19 05:10 1998-10-28 12:01 1998-11-19 12:47 1998-12-24 17:34 1999-01-22 16:00 1999-02-01 13:40 1999-02-10 12:00 1999-02-23 12:00 1999-03-17 14:20 1999-04-01 16:00 1999-04-10 00:01 1999-08-23 15:40 2001-08-14 20:45 2001-08-17 20:00 2001-09-01 16:01 2002-11-01 00:01 2002-11-16 12:45 2002-12-12 18:25 2003-03-16 00:01 2003-04-11 15:46 2003-04-30 00:45 2003-05-11 08:00 2003-05-29 08:00 2003-06-06 16:01 1993-03-09 06:00 1993-03-09 06:00 1993-09-02 10:00 1993-10-06 21:02 1994-08-13 16:00 1994-09-01 22:09 1994-10-22 10:00 1994-11-03 05:00 1995-03-27 06:00 1995-05-28 20:44 1995-09-13 23:40 1995-10-10 14:00 1996-01-15 05:10 1996-01-26 22:02 1996-09-03 04:00 1996-09-14 22:00 1996-11-11 23:50 1997-03-10 08:37 1997-04-15 14:44 1997-05-12 08:00 1997-07-01 08:00 1997-08-25 09:03 1997-12-01 08:00 1998-01-19 08:00 1998-02-05 08:30 1998-03-03 08:00 1998-04-06 01:00 1998-04-27 08:00 1998-07-27 08:50 1998-09-22 08:00 1998-10-01 00:01 1999-05-05 04:00 1999-07-01 00:01 1999-07-05 10:00 1999-08-04 00:39 1999-08-05 16:00 1999-08-13 20:00 1999-11-16 16:00 2000-01-01 00:00 2000-02-21 17:01
Finish Date-Time 1998-10-09 12:50 1998-10-18 22:03 1998-10-28 12:01 1998-11-02 08:00 1998-12-24 13:00 1999-01-22 16:00 1999-01-31 00:00 1999-02-10 12:00 1999-02-23 12:00 1999-03-17 11:30 1999-03-31 00:27 1999-04-10 00:00 1999-08-23 15:40 2001-07-26 17:05 2001-08-17 20:00 2001-09-01 16:00 2002-11-01 00:01 2002-11-16 12:45 2002-12-12 07:54 2003-03-16 00:00 2003-04-07 11:50 2003-04-28 12:40 2003-05-02 12:00 2003-05-15 16:00 2003-06-06 16:00 2003-06-12 16:00 1993-07-13 16:17 1993-07-13 16:17 1993-09-03 10:50 1994-08-05 17:55 1994-08-31 00:10 1994-09-09 09:30 1994-10-27 22:25 1994-11-05 17:02 1995-04-07 19:35 1995-06-22 12:23 1995-09-30 22:30 1995-10-12 20:00 1996-01-26 22:02 1996-02-01 03:37 1996-09-13 22:35 1996-09-15 22:37 1996-12-05 00:35 1997-03-13 22:08 1997-04-22 14:10 1997-07-01 08:00 1997-07-07 21:33 1997-09-03 17:04 1997-12-05 03:00 1998-02-01 00:01 1998-02-06 15:05 1998-03-13 16:00 1998-04-15 12:00 1998-04-30 16:00 1998-07-30 08:00 1998-10-01 00:01 1999-05-05 04:00 1999-06-16 13:53 1999-07-04 20:55 1999-07-29 16:00 1999-08-05 16:00 1999-08-13 20:00 1999-08-14 22:20 2000-01-04 23:59 2000-02-21 17:00 2000-03-09 12:33
Outage Code 43100 43100 43100 43100 43100 43100 31570 43100 43100 31570 31570 31240 41100 42100 43100 42300 42100 42110 63900 63900 63900 63900 63900 76000 71190 71190 42100 41100 42300 42120 43200 43200 99999 99999 04200 41170 31000 31000 43400 04200 52100 71000 42112 42200 42100 31000 04200 42300 99999 71190 42100 41170 42100 41100 07110 39000 39000 39000 43100 31000 41700 43100 64200 67000 44500 42112
Outage Component Amp. Outage Code Type Forced derate; all hp hea Forced derate; 4/5 hp hea Forced derate; 4/5 hp hea Stand-by; Conversion to S P P
Comments
P I
P P
I I I L
Planned Outage; 4/5 HP he Forced extension of PO; Safety valve installation fa Operating; Forced derate, 4/5 HP heaters o.o.s. Operating; Forced derate, 4/5 HP heater drains probl Operatting; FD, Boiler Safety valve passing Operating; FD, Boiler Safety valve passing Planned outage; Main gas isolator replacement Planned outage; unit annual O/H Forced Outage; Generator explosion / seal failure F.O. #6 HP Heater bled steam NRV leak F.O. Generator H2 cooler leak repair F.O. Generator repair F.O. Generator Rotor balancing problems PO; Burner Management System (BMS) upgrade PO; Burner Management System (BMS) upgrade PO; Burner Management System (BMS) upgrade PO; Burner Management System (BMS) upgrade PO; Burner Management System (BMS) upgrade PO; NH3 Storage Facility upgrade PO; CW outlet duct inspection MO; CW Outlet duct repair GENERATOR OVERHAUL TOP/EAST H2 COOLER LEAK STATOR GROUND 86-A TRIP W A" BOILER FEED PUMP "PUMP A" BOILER FEED PUMP "PUMP UNIT SHUT DOWN FOR CONVER REALIGN QUILL SHAFT, AND UNIT SHUT DOWN FOR CONVER LOSS OF LUBRICATING OIL T REPAIR HOT SPOT ON BLR. ( UNIT RESTRICTED TO 130MW 75MW B" BOILER FEED PUMP CONVERSION TO SYNCHRONOUS WORK ON THE GENERATOR MET TO REPAIR VARIOUS COOLING REPLACEMENT OF HYDROGEN S AUTOMATIC VOLTAGE REGULAT UNIT CONVERSION TO GENERA INSPECT BOILER TUBES. Conversion to synchronous Repair H2 Leakage on gene Fuel supply line outage ( Sync. Condenser operation Maintenance Outage; Gener Planned Outage, Turbine p Planned Outage; Conversio Planned Outage; Turbine B Stand-by, Forced Derate; Planned Outage; SCR insta Planned Outage; SCR installation and unit upgrade Planned Outage; SCR installation and unit upgrade Operating, Forced derate; #5 HP htr shell leak Maint. outage; Boiler furnace leak repairs Forced Outage; Speeder run down failed Stand-by; forced derate due to HP heater tube leak Forced Outage; Generator metering fault Maint. outage; East CW outlet flow measurement insta P.O. deaerator asbestos removal; in service S/C mode P.O. Generator H2 Seal Inspection/repair
P F
M P P M A
I M M I L X M M P
I E
M P
Year 1998 1998 1998 1998 1998 1998 1999 1999 1999 1999 1999 1999 1999 1999 2001 2001 2001 2002 2002 2002 2003 2003 2003 2003 2003 2003 1993 1993 1993 1993 1994 1994 1994 1994 1995 1995 1995 1995 1996 1996 1996 1996 1996 1997 1997 1997 1997 1997 1997 1998 1998 1998 1998 1998 1998 1998 1999 1999 1999 1999 1999 1999 1999 1999 2000 2000
Duration in Hours 104.83 225.22 222.85 115.98 840.22 694.43 200.00 214.33 312.00 527.50 322.12 200.00 3255.65 16873.42 71.25 356.00 10208.00 372.73 619.15 2237.58 539.82 404.90 59.25 104.00 200.00 143.98 3034.28 3034.28 24.83 7268.88 416.17 179.35 132.42 60.03 277.58 591.65 406.83 54.00 280.87 125.58 258.58 24.62 552.75 85.52 167.43 1200.00 157.55 224.02 91.00 304.02 30.58 248.00 227.00 80.00 71.17 208.02 5187.98 1017.88 92.90 582.00 39.35 196.00 26.33 1183.98 1241.00 403.53
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 02 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03
Forced State Outage Code Type 24 21 21 13 25 15 13 13 13 13 13 25 23 13 21 21 21 21 12 21 15 12 21 21 13 16 13 13 25 16 25 16 25 24 16 13 16 13 21 16 25 12 21 21 12 12 12 21 25 21 24 24 24 25 12 24 12 21 12
State Description Corrective Maintenance Outage Sudden Forced Outage Starting Failure Operating under a schedualed derating Preventive Maintenance Outage Available but not Operating under a forced derating Operating under a schedualed derating Operating under a schedualed derating Operating under a schedualed derating Operating under a schedualed derating Operating under a schedualed derating Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Operating under a schedualed derating Sudden Forced Outage Imediately Deferable Forced Outage Imediately Deferable Forced Outage Sudden Forced Outage Operating under a forced derating Imediately Deferable Forced Outage Available but not Operating under a forced derating Operating under a forced derating Sudden Forced Outage Imediately Deferable Forced Outage Operating under a schedualed derating Available but not Operating under a planned derating Operating under a schedualed derating Operating under a schedualed derating Preventive Maintenance Outage Available but not Operating under a planned derating Preventive Maintenance Outage Available but not Operating under a planned derating Preventive Maintenance Outage Corrective Maintenance Outage Available but not Operating under a planned derating Operating under a schedualed derating Available but not Operating under a planned derating Operating under a schedualed derating Sudden Forced Outage Available but not Operating under a planned derating Preventive Maintenance Outage Operating under a forced derating Sudden Forced Outage Sudden Forced Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Sudden Forced Outage Preventive Maintenance Outage Imediately Deferable Forced Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Corrective Maintenance Outage Operating under a forced derating Sudden Forced Outage Operating under a forced derating
Sync Cond Code
1 4
1 2 2 1
2
1 2
1 1 1
1 1
1
1 1
1
2
1
Common Mode Capacity Outage During Code State 0 0 0 0 155 1 0 75 155 75 155 155 155 0 0 0 150 0 0 0 0 0 150 0 150 150 0 0 142 142 142 0 160 0 0 142 1 0 142 1 0 1 0 142 142 142 142 0 0 142 0 75 0 0 80 135 135 0 0 0 0 0 0 0 0 130 0 130 0 130
Start Date-Time 2000-03-13 08:00 2000-06-05 21:00 2000-07-01 00:02 2000-07-23 22:30 2000-10-01 00:01 2000-10-17 05:20 2000-10-24 00:00 2000-10-25 17:00 2000-10-31 07:00 2000-11-01 23:30 2000-11-10 06:41 2000-12-16 13:12 2001-02-02 16:30 2001-03-16 00:00 2001-04-09 16:00 2001-04-10 17:20 2001-04-20 18:23 2002-04-09 12:10 2002-04-12 13:00 2002-04-16 11:46 2002-04-16 16:52 2002-04-18 08:00 2002-04-20 01:00 2002-04-25 03:14 2002-05-14 11:58 2002-05-15 12:15 2002-07-15 14:40 2002-08-01 00:01 2002-08-23 13:24 2002-08-24 22:08 2003-02-01 00:01 2003-02-27 09:42 2003-02-28 23:58 2003-03-14 17:01 2003-05-02 14:08 2003-05-11 08:00 2003-05-15 16:00 2003-05-29 08:00 2003-06-06 16:00 2003-06-12 16:00 2003-06-18 00:00 2003-07-04 17:10 2003-07-31 17:52 2003-08-05 23:00 2003-08-07 16:00 2004-02-20 14:10 1993-05-17 08:00 1993-06-06 15:20 1993-06-19 21:34 1993-06-22 10:38 1993-06-28 12:31 1993-07-13 14:30 1993-07-18 17:01 1993-07-31 09:20 1993-09-13 05:50 1993-09-13 05:50 1993-12-22 17:01 1994-01-13 06:01 1994-02-18 15:45 1994-03-21 03:13 1994-04-18 05:40 1994-05-16 14:07 1994-05-24 17:27 1994-05-26 17:25 1994-08-05 11:49 1994-09-07 07:20
Finish Date-Time 2000-05-04 16:00 2000-06-20 15:33 2000-07-23 22:30 2000-08-17 13:43 2000-10-17 05:20 2000-10-24 00:00 2000-10-25 17:00 2000-10-31 07:00 2000-11-01 23:30 2000-11-09 09:20 2000-12-16 07:02 2001-02-02 16:30 2001-03-16 00:00 2001-04-10 17:20 2001-04-10 17:20 2001-04-20 18:23 2002-04-08 19:25 2002-04-11 17:00 2002-04-16 10:58 2002-04-17 18:30 2002-04-17 18:30 2002-04-20 01:00 2002-04-24 11:55 2002-05-14 11:58 2002-05-15 12:15 2002-07-15 06:11 2002-07-18 22:45 2002-08-23 13:24 2002-08-24 22:08 2003-02-01 00:01 2003-02-27 09:42 2003-02-28 23:58 2003-03-14 17:01 2003-05-01 20:12 2003-05-11 08:00 2003-05-15 16:00 2003-05-29 08:00 2003-06-06 16:00 2003-06-12 16:00 2003-06-18 00:00 2003-07-04 17:10 2003-07-31 17:52 2003-08-05 23:00 2004-02-20 14:10 2003-10-03 16:00 2004-03-01 00:00 1993-06-06 15:20 1993-06-11 23:32 1993-06-22 10:30 1993-06-28 12:31 1993-07-09 19:25 1993-07-18 06:01 1993-07-21 00:01 1993-08-11 20:24 1993-12-21 16:31 1993-12-21 16:31 1994-01-07 14:36 1994-01-18 17:43 1994-03-07 20:09 1994-03-22 16:50 1994-05-16 14:07 1994-05-24 17:27 1994-05-26 01:04 1994-07-15 16:00 1994-08-11 16:00 1994-10-27 22:57
Outage Code 31000 64200 42200 44200 43100 99999 43200 43100 43200 43100 43100 43100 42100 42100 44200 43100 41100 42300 41140 64400 44200 41120 64400 41120 41120 41100 42112 41120 41120 41120 31240 31240 31240 31240 41120 76000 41120 71190 71190 41120 41120 41120 41120 42110 65300 41120 31000 43200 67000 42111 43200 43100 43100 42111 41100 42100 42110 42111 41100 42300 99999 43100 31570 43100 44200 43200
Outage Component Amp. Outage Code Type Comments P P.O. Boiler skin casing repairs Maint. outage; H2 cubicle refurbishing F.O.; Exciter fire damage Start Failure; Condensate Extraction pump failure Operating, 4/5 HP Heaters oos X Planned outage; Natural Gas supply outage Stand-by; Sched. Derate, B Boiler Feed Pump mech. Se Operating, 4/5 HP Heaters oos Operating; Sched. Derate, A Boiler Feed Pump balance Operating, 4/5 HP Heaters oos Operating, 4/5 HP Heaters oos Operating, 4/5 HP Heaters oos I Planned Outage: Generator overhaul Forced Extension of Planned Outage; Generator repair F Forced Extension of Planned Outage; Cond. Extraction Operating, 4/5 HP Heaters oos Forced Outage; Turbine failure Forced Outage; H2 leak @ casing F.O.; Bled steam line flange leak F.O.; Deaerator/Hotwell level control problem F F.O. Both cond. Extraction pumps not available O, FD; Turbine IP Rotor stages 5&6 removed F.O.; Deaerator/Hotwell level control problem ABNO ( FD); Turbine IP Rotor stages 5&6 removed O(FD); Turbine IP Rotor stages 5&6 removed V FO; Vibration FO; H2 seals oil leak into casing ABNO(SD); Turbine IP rotor stages 5&6 removed ABNO(SD); Turbine IP rotor stages 5&6 removed ABNO(SD); Turbine IP rotor stages 5&6 removed P PO; Burner Management System upgrade PO; Burner Management System upgrade PO; Burner Management System upgrade P PO; Burner Management System upgrade ABNO(SD); Turbine IP stages 5&6 removed P PO; NH3 Storage Facility upgrade ABNO(SD); Turbine IP stages 5&6 removed P PO; CW outlet duct inspection M MO; CW Outlet duct repair ABNO(SD); Turbine IP stages 5&6 removed ABNO(SD); Turbine IP stages 5&6 removed ABNO(SD); TURBINE IP STAGES 5 &6 REMOVED ABNO(SD); TURBINE IP STAGES 5 &6 REMOVED P FO; Bearing Oil failure, Rotor repair P PO; Protection Upgrade ABNO(SD); IP stages 4&5 removed I P CONVERSION TO GENERATING I "A" F.W. PP. OUT OF SERVI X 86-E TRIP EMERG.PUSH BUTT F EMERY TRIPLEVER. OIL WHIR I "A" F.W. PP. OUT OF SERVI L ALL HP HTRS OOS (RESTR TO L ALL HP HTRS OOS (REST TO NO 6 & NO 7 BRG OIL WHIRR P TURB/ALT OVERHAUL P TURB/ALT OVERHAUL P ALT. ROTOR COOLING FANS I M TO ALIGN AND FIT 2ND AND I M SYN. COND. SHUTDOWN FOR T I INSTALLING BLANKS IN THE M ALTERNATOR SHUT DOWN FOR UNIT IS IN SERVICE FOR GE M SAFETY VALVE MODIFICATION UNIT IS IN SERVICE FOR GE F COUPLING BOLTS BETWEEN PU UNIT IS I/S FOR GENERATIO
Year 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2001 2001 2001 2001 2001 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2004 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1993 1994 1994 1994 1994 1994 1994 1994 1994 1994
Duration in Hours 1256.00 354.55 550.47 591.22 389.32 162.67 41.00 134.00 40.50 177.83 864.35 1155.30 991.50 617.33 25.33 241.05 8473.03 52.83 93.97 30.73 25.63 41.00 106.92 464.73 24.28 1457.93 80.08 541.38 32.73 3841.88 633.68 38.27 329.05 1155.18 209.87 104.00 328.00 200.00 144.00 128.00 401.17 648.70 125.13 4767.17 1368.00 225.83 487.33 128.20 60.93 145.88 270.90 111.52 55.00 275.07 2386.68 2386.68 381.58 131.70 412.40 37.62 680.45 195.33 31.62 1198.58 148.18 1215.62
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03 03
Forced State Outage Code Type State Description 25 Preventive Maintenance Outage 12 Operating under a forced derating 21 1 Sudden Forced Outage 12 Operating under a forced derating 12 Operating under a forced derating 12 Operating under a forced derating 24 Corrective Maintenance Outage 12 Operating under a forced derating 21 3 Deferable Forced Outage 13 Operating under a schedualed derating 24 Corrective Maintenance Outage 12 Operating under a forced derating 25 12 12 21 25 24 24 21 24 25 25 21 21 25 15 13 24 25 25 21 13 21 12 21 12 12 24 25 13 25 13 21 13 12 13 13 21 13 12 13 13 25 24 13 13 21 13 13 25 13 13 Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Deferable Forced Outage Preventive Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Sudden Forced Outage Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Sudden Forced Outage Starting Failure Preventive Maintenance Outage Available but not Operating under a forced derating Operating under a schedualed derating Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Sudden Forced Outage Operating under a schedualed derating Sudden Forced Outage Operating under a forced derating Imediately Deferable Forced Outage Operating under a forced derating Operating under a forced derating Corrective Maintenance Outage Preventive Maintenance Outage Operating under a schedualed derating Preventive Maintenance Outage Operating under a schedualed derating Imediately Deferable Forced Outage Operating under a schedualed derating Operating under a forced derating Operating under a schedualed derating Operating under a schedualed derating Imediately Deferable Forced Outage Operating under a schedualed derating Operating under a forced derating Operating under a schedualed derating Operating under a schedualed derating Preventive Maintenance Outage Corrective Maintenance Outage Operating under a schedualed derating Operating under a schedualed derating Starting Failure Operating under a schedualed derating Operating under a schedualed derating Preventive Maintenance Outage Operating under a schedualed derating Operating under a schedualed derating
Sync Cond Code
3
1
1 4
1
1 1 2
2
2
4
Common Mode Capacity Outage During Code State 0 130 0 130 100 130 0 130 0 140 0 130 0 0 140 135 0 0 0 0 0 0 0 1 0 0 0 0 40 160 0 0 0 0 0 0 150 0 150 0 75 70 0 0 155 1 0 155 0 155 75 155 155 0 155 75 155 150 1 0 0 150 150 0 150 150 0 150 75
Start Date-Time 1994-10-27 22:57 1994-11-03 02:35 1994-11-27 07:55 1994-11-30 09:08 1994-12-05 22:00 1994-12-14 13:10 1995-01-06 16:00 1995-01-31 14:35 1995-03-18 09:52 1995-07-19 08:00 1995-07-21 22:10 1995-08-13 15:15 1995-08-18 11:25 1995-08-18 11:25 1995-09-13 16:50 1995-10-10 14:00 1995-10-11 23:02 1995-10-22 22:00 1996-09-14 22:05 1996-11-06 12:50 1997-04-10 09:45 1997-04-25 05:03 1997-12-01 08:00 1998-01-19 08:00 1998-03-09 11:44 1998-03-11 08:00 1998-06-01 08:00 1998-07-27 08:50 1999-04-01 16:00 1999-07-24 08:00 1999-08-09 08:00 1999-11-02 22:00 1999-11-17 02:10 2000-04-05 17:00 2000-06-01 17:00 2000-06-03 04:30 2000-06-04 17:00 2000-06-08 21:00 2000-06-20 18:06 2000-07-06 03:07 2000-08-10 10:55 2000-09-01 00:01 2000-09-17 08:00 2000-10-13 16:00 2000-10-17 08:05 2000-10-24 05:00 2000-11-06 11:37 2000-11-14 22:22 2000-12-12 15:35 2000-12-14 00:00 2000-12-28 00:00 2001-01-19 15:20 2001-01-20 17:20 2001-01-21 18:50 2001-01-23 20:19 2001-02-12 12:20 2001-04-23 07:00 2001-05-02 20:00 2001-05-08 12:19 2001-05-25 10:15 2001-07-02 09:36 2001-07-05 22:20 2001-07-10 13:30 2001-07-27 20:00 2001-08-22 00:00 2001-09-12 06:00
Finish Date-Time 1994-11-03 01:20 1994-11-27 07:55 1994-11-30 09:08 1994-12-05 22:00 1994-12-14 13:10 1994-12-21 16:00 1995-01-26 16:00 1995-02-10 08:00 1995-03-20 02:20 1995-07-20 16:00 1995-07-24 09:47 1995-08-18 11:25 1995-09-13 16:50 1995-09-13 16:50 1995-10-03 19:00 1995-10-11 23:02 1995-10-15 03:20 1995-11-24 15:00 1996-09-26 16:15 1996-11-07 18:00 1997-04-25 05:03 1997-06-28 05:15 1997-12-05 03:00 1998-02-01 00:01 1998-03-11 08:00 1998-03-14 16:26 1998-06-14 23:30 1998-07-30 08:00 1999-04-10 00:00 1999-08-01 13:27 1999-11-02 22:00 1999-11-17 02:10 2000-04-05 17:00 2000-05-31 20:25 2000-06-03 04:30 2000-06-04 16:35 2000-06-08 18:10 2000-06-14 08:00 2000-06-22 00:05 2000-07-08 12:30 2000-09-01 00:01 2000-09-05 09:44 2000-10-12 14:55 2000-10-17 08:05 2000-10-23 23:15 2000-11-06 11:37 2000-11-14 22:22 2000-12-12 15:35 2000-12-14 00:00 2000-12-27 18:39 2001-01-19 15:20 2001-01-20 17:20 2001-01-21 18:50 2001-01-22 22:35 2001-02-12 11:20 2001-04-23 02:58 2001-05-02 20:00 2001-05-07 05:36 2001-05-25 05:00 2001-07-02 09:06 2001-07-05 18:00 2001-07-10 12:00 2001-07-27 08:00 2001-08-21 00:00 2001-09-12 06:00 2001-09-18 15:00
Outage Code 99999 43200 31000 43200 43200 43200 43200 43100 31540 43200 31540 43100 41100 42100 43200 31000 31000 04200 52100 52120 31000 42100 99999 71190 52130 41200 42112 07110 31240 42300 39000 39000 39000 39000 31270 43100 31570 43100 44500 53200 41160 41160 42200 43100 99999 43100 31540 43100 43400 43100 43100 41160 43100 41160 43100 43100 72000 31540 43100 43100 41120 43100 43100 31000 43100 43200
Outage Component Amp. Outage Code Type Comments M VARIOUS REPAIRS TO EXTERN UNIT I/S FOR GENERATION. F 5 INCH SPLIT IN SWEDGE J UNIT I/S FOR GENERATION. A BOILER FW PP O.O.S. FOR B BOILER FW PP O.O.S. FOR I INSECTION/REPAIR TO A BOI L NO HP HTRS. OUT FOR REPAI L WATERWALL TUBE LEAK @ EN 140MW A" BOILER FW PP LEA L M OUTAGE #6102, LOWER BOILE L 130MW NO HIGH PRESSURE FE P UNIT IS ON ANNUAL OVERHAU UNIT IS ON ANNUAL OVERHAU BOILER FEED PUMP LEAK OFF A UNIT RESTRICTED TO 135MW F UNIT SHUTDOWN FOR ECONOMI P UNIT SHUT DOWN FOR CONVER I METER CHANGES TO GENERATO I M VOLTAGE REGULATOR MULTIPLE BOILER TUBE FAIL I SYNC. COND. S/D AND OUTAG X Fuel supply line outage ( Sync. Condenser operation Forced Outage; Unit servi Starting Failure; Jacking Planned outage; Generator E Stand-by, Forced Derate; Planned outage; Main gas valve replacement Maint. outage; H2 system modifications P Planned outage; SCR insta Planned outage; SCR install & unit upgrade, Gen H2 c P Planned outage; SCR install & unit upgrade, Gen H2 c Planned outage; SCR install & unit upgrade F.O; Pilot igniter air failure Operating, S.D.; HP FW heater #6 o.o.s. F.O. Safety valve fail to reseat Operating, S.D.; HP FW heater #6 o.o.s. F. O., Deaerator level column leak Operating, F.D., BFP motor 4kV cable fault Operating FD; Governor valve gland leak-off flange Maint. Outage; Governor valve gland leak-off flange Planned Outage; AVR upgrade Operating, 4/5 HP Heaters oos X Planned outage; Natural Gas supply outage Operating, 4/5 HP Heaters oos Forced Outage; Boiler wall tube leak Operating, 4/5 HP Heaters oos Operating, forced derate; "B" BFP motor brg vibratio Operating, 4/5 HP Heaters oos Operating, 4/5 HP Heaters oos Forced outage; #2 Governor valve fail (not in CCOR) Operating, 4/5 HP Heaters oos Operating, FD; #4 HP Gov valve gland leak-off flange Operating, 4/5 HP Heaters oos Operating, 4/5 HP Heaters oos Planned Outage; Stn FW system inspect / repair Maint. Outage; Boiler tube leak repair Operating SD; 4/5 HP Heaters oos. Operating SD; 4/5 HP Heaters oos. Start failure, Unit coolout required due to suspect IP rotor Operating SD; 4/5 HP Heaters oos. Operating SD; 4/5 HP Heaters oos. Planned outage Operating,SD; 4/5 HP heaters o.o.s. Operating,SD; Boiler Feed pump repair
Year 1994 1994 1994 1994 1994 1994 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1996 1996 1997 1997 1997 1998 1998 1998 1998 1998 1999 1999 1999 1999 1999 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001
Duration in Hours 146.38 581.33 73.22 132.87 207.17 170.83 480.00 233.42 40.47 32.00 59.62 116.17 629.42 629.42 482.17 33.03 76.30 785.00 282.17 29.17 355.30 1536.20 91.00 304.02 44.27 80.43 327.50 71.17 200.00 197.45 2054.00 340.17 3374.83 1347.42 35.50 36.08 97.17 131.00 29.98 57.38 517.10 105.72 606.92 88.08 159.17 318.62 202.75 665.22 32.42 330.65 543.33 26.00 25.50 27.75 471.02 1670.63 229.00 105.60 400.68 910.85 80.40 109.67 402.50 580.00 510.00 153.00
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 03 03 03 03 03 03 03 03 03 03 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04
Forced State Outage Code Type State Description 13 Operating under a schedualed derating 16 Available but not Operating under a planned derating 13 Operating under a schedualed derating 21 3 Deferable Forced Outage 21 3 Deferable Forced Outage
Sync Cond Code
25 24 21 21 21 25 21 24 12 12 12 12 21 12 25 12 12 12 21 21 12 24 12 12 21 12 21 25 25 12 21 24 24 24 24 24 24 24 25 21 25 21 25 21 24 12 21 24 24 12 12 12 12 12 12 13 25
3 3 1 1
1
Preventive Maintenance Outage Corrective Maintenance Outage Deferable Forced Outage Deferable Forced Outage Sudden Forced Outage Preventive Maintenance Outage Sudden Forced Outage Corrective Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Sudden Forced Outage Operating under a forced derating Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Deferable Forced Outage Deferable Forced Outage Operating under a forced derating Corrective Maintenance Outage Operating under a forced derating Operating under a forced derating Sudden Forced Outage Operating under a forced derating Sudden Forced Outage Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Deferable Forced Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Starting Failure Preventive Maintenance Outage Sudden Forced Outage Preventive Maintenance Outage Starting Failure Corrective Maintenance Outage Operating under a forced derating Sudden Forced Outage Corrective Maintenance Outage Corrective Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a schedualed derating Preventive Maintenance Outage
3 3
1 1
3
4 1 4
1
Common Mode Capacity Outage During Code State 150 150 150 0 0 0 0 0 0 0 0 0 0 0 0 0 100 100 75 75 0 100 0 0 100 100 100 0 0 75 0 110 75 0 128 0 0 0 112 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 125 0 0 0 110 40 1 142 1 136 1 140 1 144 115 0
Start Date-Time 2001-09-18 15:00 2001-10-23 14:20 2001-10-29 15:30 2001-11-18 22:00 2001-12-03 16:16 2001-12-12 12:01 2001-12-15 21:51 2003-05-01 00:00 2003-06-20 09:34 2003-12-07 10:30 1993-04-25 22:02 1993-07-10 09:25 1993-09-11 09:30 1993-10-31 12:07 1994-03-24 17:06 1994-04-02 16:00 1994-05-19 09:33 1994-07-04 23:59 1994-08-22 10:52 1994-08-26 00:04 1994-09-06 02:07 1994-09-07 21:30 1994-09-24 07:20 1994-09-24 07:20 1994-10-08 14:30 1994-10-14 09:20 1994-10-19 11:36 1994-11-23 04:04 1994-12-27 22:00 1995-06-14 08:00 1995-07-02 19:00 1995-07-06 02:37 1995-09-30 21:30 1995-10-04 18:50 1995-10-09 19:25 1995-10-14 19:50 1995-10-17 02:52 1996-03-21 13:46 1996-09-12 08:00 1996-09-23 03:10 1996-10-27 08:00 1996-11-21 17:59 1996-12-10 08:00 1997-02-18 05:05 1997-04-01 10:00 1997-08-09 00:08 1997-10-06 08:00 1997-11-30 08:00 1997-12-07 05:36 1997-12-11 08:00 1998-01-17 09:18 1998-03-02 11:05 1998-03-23 11:07 1998-04-07 12:00 1998-04-21 06:00 1998-04-22 06:42 1998-06-07 12:03 1998-07-17 22:04 1998-07-20 20:09 1998-07-27 08:50 1998-08-02 00:00 1998-08-19 06:00 1998-08-21 06:00 1998-08-23 06:00 1998-08-29 08:00 1999-03-01 10:00
Finish Date-Time 2001-10-23 14:20 2001-10-29 11:50 2001-11-16 08:00 2001-12-03 16:16 2001-12-12 12:01 2001-12-15 21:51 2002-08-22 23:22 2003-06-20 09:33 2003-07-22 09:33 2003-12-08 20:00 1993-05-01 01:34 1993-07-14 19:40 1993-09-12 10:47 1993-11-04 07:45 1994-04-02 16:00 1994-04-29 20:25 1994-07-04 22:00 1994-08-05 11:20 1994-08-25 23:30 1994-09-06 02:07 1994-09-07 21:30 1994-09-24 07:20 1994-10-08 11:50 1994-10-08 11:50 1994-10-14 08:52 1994-10-19 09:20 1994-10-21 16:00 1994-12-01 22:06 1994-12-29 01:53 1995-06-17 02:00 1995-07-04 16:00 1995-07-07 20:30 1995-10-02 09:00 1995-10-09 19:25 1995-10-11 05:20 1995-10-15 21:35 1995-10-23 20:15 1996-09-06 18:10 1996-09-13 16:30 1996-09-24 13:15 1996-10-31 23:15 1996-11-23 02:43 1996-12-11 23:25 1997-02-21 10:15 1997-04-04 16:00 1997-08-11 08:00 1997-10-08 14:00 1997-12-07 05:36 1997-12-11 08:00 1998-01-14 13:08 1998-02-25 09:52 1998-03-23 11:07 1998-04-06 19:00 1998-04-08 16:00 1998-04-22 06:42 1998-04-24 01:57 1998-06-09 04:01 1998-07-20 20:09 1998-07-21 22:40 1998-07-30 08:00 1998-08-04 06:00 1998-08-21 06:00 1998-08-23 06:00 1998-08-24 07:05 1998-08-30 15:25 1999-03-31 23:59
Outage Code 43100 43100 43100 41540 41540 41540 41540 31240 31240 72000 33100 31000 31240 04200 51151 04200 43200 43400 43400 43400 65200 43400 41100 42100 43400 43400 43400 42300 33100 34100 41140 43200 31000 41160 31000 71000 04200 42100 43200 31703 31280 43090 04200 04200 42100 41100 33100 31000 42110 42100 42300 31570 42120 41700 31570 65300 31270 33100 43200 07110 07210 07210 07210 07210 43200 42200
Outage Component Amp. Outage Code Type
F F P
L F F M F
F
P
L L L D
P
M
F A F P P F M
I I L I L
I
P
E E E E E
Comments Operating,SD; 4/5 HP heaters o.o.s. Stand-by Operating,SD; 4/5 HP heaters o.o.s. Forced Outage; Turbine IP Gland fail Forced Outage; Turbine IP Gland fail Forced Outage; Turbine IP Gland fail Forced Outage; Turbine IP Gland fail PO; Burner Management System upgrade PO; Burner Management System upgrade based on CM. Unit off line when water supply pipe failed and no MAIN STEAM PIPE STOP U/U HTSH PENDENT TUBE/FURNACE WRONG CAM IN MAIN GAS REY CONVERSION TO SYNC COND M WO.#919629 GROUND FAULT O UNIT CONVERSION BACK TO G UNIT RESTRICTED TO 100 MW UNIT RESTRICTED TO 100 MW UNIT RESTRICTED TO 75 MW UNIT RESTRICTED TO 75 MW T14 STATION TRANSFORMER T UNIT RESTRICTED TO 100 MW UNIT SHUTDOWN FOR ITS ANN UNIT SHUTDOWN FOR ITS ANN UNIT RESTRICTED TO 100 MW UNIT RESTRICTED TO 100 MW UNIT RESTRICTED TO 100 MW SHUTDOWN FOR HYDROGEN LEA REPAIR BREACH BLOCK LEAK FURNACE GAS LEAK 4TH LEVE TURBINE LOW PRESSURE CROS 110MW B" BOILER FW PP AC SALT WATER ENTERIFNG INTO #3 HP GOVERNOR VALVE STUC BOILER HIGH SILICA, UNIT WEST CW PUMP DISCH HEADER UNIT IS SHUT DOWN FOR CON OUTAGE #2305, MAINTENANCE BRG. INSPECTION OF THE "A TWO TUBE LEAKS IN THE ECO INSTALL PILOT FLAME SCANN UNIT SHUTDOWN FOR VARIOUS CONVERSION TO SYNCHRONOUS UNIT CONVERSION FROM SYNC HIGH POT TESTING FOR STAT Various repairs to turbin Maint. Outage; Unit isola Planned Outage; Boiler in Forced Outage; Generator Planned Outage; Generator Forced Outage; Generator Planned Outage; Boier Saf Starting Failure; Stator Vac. payoff linkage repai Forced Derate; safety val Forced Outage; Regulated Maint. outage for flame s Maint. outage; main steam Forced derate; "B" BFP ba Forced Derate; Regional A Forced derate; Cooling wa Forced derate; CW permit Forced derate; CW permit Forced derate; CW permit Scheduled derate; "A" BFP Planned Outage; AVR replacement
Year 2001 2001 2001 2001 2001 2001 2001 2003 2003 2003 1993 1993 1993 1993 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1995 1995 1995 1995 1995 1995 1995 1995 1996 1996 1996 1996 1996 1996 1997 1997 1997 1997 1997 1997 1997 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1999
Duration in Hours 839.33 141.50 424.50 354.27 211.75 81.83 6001.52 1209.55 767.98 33.50 123.53 106.25 25.28 91.63 214.90 652.42 1116.45 755.35 84.63 266.05 43.38 393.83 340.50 340.50 138.37 120.00 52.40 210.03 27.88 66.00 45.00 41.88 35.50 120.58 33.92 25.75 161.38 4060.40 32.50 34.08 111.25 32.73 39.42 77.17 78.00 55.87 54.00 165.60 98.40 821.13 936.57 504.03 343.88 28.00 24.70 43.25 39.97 70.08 26.52 71.17 54.00 48.00 48.00 25.08 31.42 733.98
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 04 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05
Forced State Outage Code Type State Description 23 Forced Extention of a Preventive Maintenance Outage 13 Operating under a schedualed derating 24 Corrective Maintenance Outage 24 Corrective Maintenance Outage 24 Corrective Maintenance Outage 24 Corrective Maintenance Outage 24 Corrective Maintenance Outage 25 Preventive Maintenance Outage 25 13 24 21 13 25 23 16 13 13 12 25 21 21 25 23 21 12 25 21 25 21 24 25 25 25 21 24 21 24 24 21 21 25 25 21 21 12 21 21 24 12 15 12 15 12 21 21 12 24 16 21 12 24 24 25 Preventive Maintenance Outage Operating under a schedualed derating Corrective Maintenance Outage Sudden Forced Outage Operating under a schedualed derating Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Available but not Operating under a planned derating Operating under a schedualed derating Operating under a schedualed derating Operating under a forced derating Preventive Maintenance Outage Imediately Deferable Forced Outage Starting Failure Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Imediately Deferable Forced Outage Operating under a forced derating Preventive Maintenance Outage Deferable Forced Outage Preventive Maintenance Outage Starting Failure Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Sudden Forced Outage Corrective Maintenance Outage Starting Failure Corrective Maintenance Outage Corrective Maintenance Outage Deferable Forced Outage Deferable Forced Outage Preventive Maintenance Outage Preventive Maintenance Outage Sudden Forced Outage Sudden Forced Outage Operating under a forced derating Deferable Forced Outage Deferable Forced Outage Corrective Maintenance Outage Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Available but not Operating under a forced derating Operating under a forced derating Deferable Forced Outage Sudden Forced Outage Operating under a forced derating Corrective Maintenance Outage Available but not Operating under a planned derating Deferable Forced Outage Operating under a forced derating Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage
Sync Cond Code
1
2 4
2
3
4
1 4
3 3
1 1 3 3
3 1
3
Common Mode Capacity Outage During Code State 0 40 0 0 0 0 0 0 0 0 100 1 0 0 110 0 0 110 110 110 150 1 0 0 0 0 0 0 130 1 0 0 0 0 0 0 0 1 0 1 0 0 0 0 0 0 0 0 0 0 1 0 0 143 0 0 0 110 110 110 110 112 0 0 112 0 130 0 135 0 0 0
Start Date-Time 1999-03-31 23:59 1999-05-25 08:47 1999-06-01 08:00 1999-06-23 08:00 1999-07-24 08:00 1999-10-20 08:00 1999-11-03 16:01 1999-11-13 00:00 1999-12-12 23:20 2000-02-23 05:01 2000-03-03 09:00 2000-04-24 08:00 2000-06-01 21:40 2000-06-12 01:45 2000-10-30 08:00 2000-11-25 00:00 2000-12-04 16:00 2001-01-12 14:00 2001-01-17 08:45 2001-04-01 00:01 2001-04-23 08:17 2001-07-22 23:40 2001-07-24 00:00 2001-08-25 07:55 2001-10-05 00:00 2001-10-21 08:32 2001-10-23 11:18 2002-02-11 06:58 2002-06-11 12:00 2002-08-19 08:00 2002-08-25 03:30 2003-02-27 11:42 2003-03-27 08:00 2003-05-08 08:00 2003-05-15 16:01 2003-05-17 00:01 2003-09-28 18:35 2003-10-17 16:00 2003-11-26 19:00 2004-01-03 00:00 1993-09-27 08:00 1994-01-07 19:05 1994-02-14 16:00 1994-02-23 08:00 1994-10-02 11:50 1995-10-03 17:50 1995-10-14 19:57 1995-10-16 14:30 1995-10-17 16:15 1995-12-18 03:45 1996-06-01 00:01 1996-08-19 11:30 1996-08-20 23:08 1996-08-23 08:05 1996-08-30 23:00 1996-09-03 06:30 1996-09-07 00:25 1996-09-09 11:53 1996-09-18 07:38 1996-10-31 08:00 1997-02-24 13:15 1997-03-05 14:17 1997-04-08 08:50 1997-07-14 17:36 1997-10-06 08:18 1997-11-19 16:00
Finish Date-Time 1999-05-25 08:47 1999-05-26 09:00 1999-06-16 16:00 1999-06-30 16:00 1999-08-05 23:20 1999-11-03 16:00 1999-11-13 00:00 1999-12-12 23:20 2000-02-23 05:00 2000-03-02 14:00 2000-03-04 16:00 2000-05-06 16:00 2000-06-02 23:30 2000-06-30 17:08 2000-11-25 00:00 2000-12-04 16:00 2001-01-12 14:00 2001-01-17 08:30 2001-01-18 12:58 2001-04-23 08:17 2001-05-02 04:48 2001-07-24 00:00 2001-07-25 20:12 2001-10-05 00:00 2001-10-20 13:46 2001-10-23 11:18 2001-10-24 15:18 2002-02-16 00:00 2002-08-13 10:54 2002-08-25 03:30 2003-01-31 18:30 2003-02-28 12:21 2003-04-07 08:00 2003-05-15 16:00 2003-05-17 00:00 2003-05-26 22:00 2003-09-29 19:34 2003-10-22 13:40 2003-12-10 08:00 2004-01-05 16:00 1993-10-10 21:20 1994-01-13 22:42 1994-02-23 08:00 1994-04-15 15:50 1995-05-09 05:40 1995-10-05 16:39 1995-10-15 23:52 1995-10-17 16:15 1995-10-19 03:10 1996-01-26 16:00 1996-08-19 11:30 1996-08-20 23:08 1996-08-23 08:05 1996-08-30 23:00 1996-09-03 06:30 1996-09-07 00:25 1996-09-08 17:57 1996-09-18 07:38 1996-09-27 18:15 1997-02-08 08:00 1997-03-03 19:00 1997-03-07 21:30 1997-04-10 10:40 1997-08-06 08:27 1997-11-19 16:00 1998-02-01 08:00
Outage Code 42200 42200 41100 41170 42300 42300 42100 63900 63900 63900 63900 71190 65100 43400 31000 44500 43260 43260 43260 41160 72000 63100 41120 41100 41100 41200 31000 71000 42110 63100 63100 42200 43090 65100 71190 71190 42200 42200 41160 44120 99999 42112 41700 31000 63100 71000 71000 31000 31000 41160 31000 43200 43200 43200 43200 43200 34100 43200 43200 43100 43100 31000 31000 43100 42110 41120
Outage Component Amp. Outage Code Type
P P
I
F A P V P
M I
L F I P M F F F I M
I F I I I
M
L M P
Comments Foced extension of PO; AVR replacement AVR comissioning Maint. outage; T-G alignment correction Maint. outage; #5 bearing inspection / repair Maint. outage; H2 system modifications M.O.; Hydrogen cooler gaskets replace M.O.; Generator repairs P.O. ; Burner Management System upgrade P.O. ; Burner Management System upgrade; S/C operati P.O. ; Burner Management System upgrade; S/C shut do BMS commissioning M.O. CW outlet duct cleaning F.O. Lightning strike Operating, F.D.; "B" boiler feedwater pump motor fai Planned Outage; annual inspection & maintenance Forced Ext. Of PO; Deaerator repairs Stand-by; "B" BFP variable speed coupling overhaul Operating, sched. Derate; "B" BFP variable speed cou Operating, sched. Derate; "B" BFP variable speed cou Operating, F.D.; Turbine Gov valve fail to open full Planned Outage; Stn FW system inspect / repair F.O.; FD fan controller fire Start failure, Unit coolout required due to suspect IP rotor Planned outage; Turbine o/h, blr inspection & repairs Forced Extension of Planned Outage; Turbine Overhaul Forced Outage; Turbine oil leaks Operating, Forced Derate; Boiler water silica Planned outage of CW system; unit in S/C operation F.O.; Generator vibration PO; DCS upgrade PO; DCS upgrade FO; AVR Failure MO: Feedwater Line Repairs PO; Install T4 transformer bushing monitoring equipment PO; CW OUTLET DUCT INSPECTION MO; CW Outlet duct repair FO; Exciter trip previous 14. Listed as FO in CM) FO; #3 HP Governor Valve sticking MO; Condenser Tube leak repair INSPECTION OF AIR PRE-HTR ALT. OUTBOARD SEAL LEAKAG FREE UP AND REPLACE CRACK ANNUAL INSPECTION AND REP UNIT OUTAGE FOR SCR INSTA ELECTRICAL SHORT. CAUSED WEST CW PUMP DISCH HEADER 143MW HOT SPOT ON WEST SI REPAIR HOT SPOT ON BOILER #4 HP GOVERNOR V/V BROKEN UNIT IS OUT OF SERVICE FO UNIT IS IN SERVICE FOR GE UNIT IS SHUT DOWN DUE TO UNIT IS IN SERVICE FOR GE UNIT IS SHUT DOWN DUE TO BOILER FEEDWATER PUMP RE FURNACE HOT SPOT CAUSING LOSS OF BOILER FEED PUMP. UNIT IS IN SERVICE WITH A NEW HP FW HTRS REPLACEMEN UNIT IS ON 6 HOUR STANDBY UNIT S/D DUE TO BOILER WA UNIT IS DERATED DUE TO BO Repairs to F.W. Heater va Maint. Outage; Generator Maint. Outage; Turbine bl
Year 1999 1999 1999 1999 1999 1999 1999 1999 1999 2000 2000 2000 2000 2000 2000 2000 2000 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2002 2002 2002 2002 2003 2003 2003 2003 2003 2003 2003 2003 2004 1993 1994 1994 1994 1994 1995 1995 1995 1995 1995 1996 1996 1996 1996 1996 1996 1996 1996 1996 1996 1997 1997 1997 1997 1997 1997
Duration in Hours 1304.80 24.22 368.00 176.00 303.33 344.00 223.98 719.33 1733.67 200.98 31.00 296.00 25.83 447.38 616.00 232.00 934.00 114.50 28.22 536.27 212.52 24.33 44.20 976.08 373.77 50.77 28.00 113.03 1510.90 139.50 3831.00 24.65 264.00 176.00 31.98 237.98 24.98 117.67 325.00 64.00 325.33 147.62 208.00 1231.83 5249.83 46.82 27.92 25.75 34.92 948.25 1907.48 35.63 56.95 182.92 79.50 89.92 41.53 211.75 226.62 2400.00 173.75 55.22 49.83 542.85 1063.70 1768.00
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 05 06 06 06 06 06 06
State Code 23 25 12 12 12 12 12 12 21 25 23 25 24 22 24 16 13 16 13 16 12 15 24 12 25 21 24 24 21 25 24 12 21 21 24 25 24 24 12 12 25 25 23 25 13 24 13 15 25 25 13 13 21 25 15 25 25 24 24 25 24 12 25 21 25
Forced Outage Type
2
1
1
2 1
2
State Description Forced Extention of a Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Imediately Deferable Forced Outage Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Forced Extention of a Corrective Maintenance Outage Corrective Maintenance Outage Available but not Operating under a planned derating Operating under a schedualed derating Available but not Operating under a planned derating Operating under a schedualed derating Available but not Operating under a planned derating Operating under a forced derating Available but not Operating under a forced derating Corrective Maintenance Outage Operating under a forced derating Preventive Maintenance Outage Sudden Forced Outage Corrective Maintenance Outage Corrective Maintenance Outage Sudden Forced Outage Preventive Maintenance Outage Corrective Maintenance Outage Operating under a forced derating Imediately Deferable Forced Outage Sudden Forced Outage Corrective Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Preventive Maintenance Outage Operating under a schedualed derating Corrective Maintenance Outage Operating under a schedualed derating Available but not Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Operating under a schedualed derating Operating under a schedualed derating Imediately Deferable Forced Outage Preventive Maintenance Outage Available but not Operating under a forced derating Preventive Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Operating under a forced derating Preventive Maintenance Outage Sudden Forced Outage Preventive Maintenance Outage
Sync Cond Code
1
Common Mode Capacity Outage During Code State 0 0 40 1 142 1 144 1 140 1 144 123 0 0 0 1 0 0 0 0 110 110 110 110 110 150 150 0 150 0 0 1 0 0 0 0 0 110 0 0 0 1 0 0 0 110 150 0 0 0 1 0 125 0 110 110 0 0 45 110 0 0 80 1 0 1 0 1 0 1 0 0 0 115 0 0 0 0
Start Date-Time 1998-02-01 08:00 1998-03-17 09:20 1998-07-27 08:50 1998-08-02 00:00 1998-08-18 06:00 1998-08-21 06:00 1998-08-23 06:00 1998-11-13 07:05 1998-12-25 18:02 1999-01-26 07:00 1999-03-08 16:00 1999-04-01 16:00 1999-05-05 08:00 1999-05-06 14:05 1999-06-07 08:00 1999-06-24 08:00 1999-06-29 05:39 1999-07-02 02:20 1999-07-08 08:45 1999-07-14 20:08 1999-08-05 08:00 1999-08-09 23:00 1999-08-12 08:00 1999-08-22 03:22 1999-10-07 12:00 1999-11-13 17:45 1999-11-27 08:04 1999-12-02 22:01 1999-12-16 09:05 2000-03-10 08:00 2000-04-07 08:01 2000-06-09 13:07 2000-06-28 05:00 2000-07-17 01:30 2000-09-11 08:00 2000-10-17 08:05 2000-10-24 00:00 2000-12-28 10:30 2001-01-06 06:50 2001-03-12 00:15 2001-04-14 08:04 2001-10-15 08:00 2001-11-24 00:00 2002-02-11 06:58 2002-03-01 00:01 2002-03-08 08:00 2002-03-16 23:20 2002-04-01 07:55 2002-05-22 08:30 2002-10-20 21:38 2002-10-21 22:09 2002-10-23 16:00 2002-10-29 08:21 2003-02-17 08:00 2003-04-09 18:32 2003-05-11 08:00 2003-05-14 16:01 2003-05-17 00:00 2003-12-07 10:30 2004-01-12 08:00 1993-05-30 01:20 1993-07-31 10:15 1993-10-12 09:56 1993-10-12 09:56 1993-10-23 11:40 1994-02-23 08:00
Finish Date-Time 1998-02-15 13:05 1998-04-09 12:37 1998-07-30 08:00 1998-08-04 06:00 1998-08-19 09:00 1998-08-23 06:00 1998-08-24 21:40 1998-11-20 11:40 1998-12-27 02:55 1999-03-08 16:00 1999-03-30 11:27 1999-04-10 00:00 1999-05-06 14:05 1999-05-12 18:10 1999-06-11 16:00 1999-06-29 05:39 1999-07-02 02:20 1999-07-08 08:45 1999-07-14 20:08 1999-07-16 16:00 1999-08-09 23:00 1999-08-12 08:00 1999-08-21 06:00 1999-09-01 00:01 1999-11-13 14:07 1999-11-18 10:05 1999-12-02 22:00 1999-12-04 02:42 1999-12-17 20:00 2000-04-07 08:00 2000-06-09 13:07 2000-06-13 16:30 2000-06-29 21:50 2000-08-03 10:05 2000-09-12 18:35 2000-10-24 00:00 2000-10-25 13:52 2001-01-05 19:55 2001-01-11 14:15 2001-03-13 17:30 2001-05-05 02:47 2001-11-24 00:00 2001-12-17 14:00 2002-02-16 00:00 2002-03-04 20:30 2002-03-12 16:00 2002-04-01 07:55 2002-05-22 08:30 2002-10-20 16:44 2002-10-21 22:09 2002-10-23 16:00 2002-10-24 19:30 2002-11-05 00:00 2003-03-15 00:00 2003-04-22 12:00 2003-05-14 16:00 2003-05-17 00:00 2003-05-26 22:00 2003-12-08 20:00 2004-02-20 16:00 1993-05-31 04:20 1993-08-01 19:30 1993-10-23 10:10 1993-10-23 10:10 1993-10-28 22:48 1994-04-10 03:02
Outage Code 41100 31000 07110 07210 07210 07210 07210 51120 31540 63900 63900 31240 43100 33200 44500 43260 43260 43260 43260 43260 43260 43260 42300 43260 42200 42111 67000 42100 51133 42100 42100 43260 41100 42100 48200 99999 31570 44120 43400 43100 31000 41100 41120 71000 31000 73100 43400 43400 63100 63100 63100 63100 44120 31000 63200 76000 71190 71190 72000 33100 99999 43200 41100 42100 44110 31000
Outage Component Amp. Outage Code Type F I E E E E E
M M
X L
A
I
L I
P P F P
Comments Forced extension of PO; D Planned Outage; Air Prehe Forced Derate; Regional A Forced derate; Cooling wa Forced derate; CW permit Forced derate; CW permit Forced derate; CW permit Operating, Forced derate; Forced outage; Furnace fl Burner Management System upgrade Forced extension of PO; BMS upgrade Planned outage; Main gas isolator replacement M.O. HP heaters vent to deaerator repair M.O. Reheat strainer repair Maint. outage; deaerator safety valve repair Stand-by, scheduled derate; BFP fluid coupling inspe Operating, scheduled derate; BFP fluid coupling insp Stand-by, scheduled derate; BFP fluid coupling repa Operating, scheduled derate; BFP fluid coupling repa Stand-by, scheduled derate; BFP fluid coupling repa Operating, forced derate; BFP fluid coupling derate Stand-by, forced derate; BFP fluid coupling derate Maint. outage; H2 system modifications Operating, forced derate; BFP fluid coupling derate Planned outage; AVR upgrade Forced outage; Generator bearing vibration Maint. outage; West CW outlet flow measurement insta Maint. outage; Generator balancing F.O.; 2CB14 "B" phase open Planned outage; Generator seals, coolers, balancing, Maintenance Outage; Generator repairs Operating, F.D.; "B" BFP fluid coupling oil leaks F.O; HP Flange warming line repair Forced Outage; Generator neut. bushing fail Maint. outage; Feedwater heater drains (VH30) repair Planned outage; Natural Gas supply outage Maint. Outage safety valve maintenance Maint. Outage; Condenser leak repair Operating, Forced derate; B boiler feed pump motor t Forced derate; HP Heater condensate drain flange lea Planned Outage; Annual inspection Planned outage; Turbine o/h, blr inspection & repairs Forced Extension of PO; IP rotor blading Planned outage of CW system Operating, SD; boiler water quality Maint Outage, Esso steam supply modifications Operating, FD; BFP motor winding fault Stand-by, FD; BFP motor winding fault PO; DCS upgrade PO; DCS upgrade O(SD); DCS commissioning O(SD); DCS commissioning Condensate & boiler water PO; Annual Inspection ABNO(FD); FD Fan control probleem PO; NH3 Storage Facility upgrade PO; CW OUTLET DUCT INSPECTION MO; CW Outlet duct repair based on CM. Unit off line when water supply pipe failed and no PO; Asbestos abatement WORK ON VARIOUS VALVES B BF PP MECH SEAL REPAIR PLANNED OUTAGE OVERHAUL PLANNED OUTAGE OVERHAUL LP CROSS-OVER PIPE VACUME COOLING WATER WATER BOX R
Year 1998 1998 1998 1998 1998 1998 1998 1998 1998 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 2000 2000 2000 2000 2000 2000 2000 2000 2000 2001 2001 2001 2001 2001 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2003 2003 2003 2003 2003 2003 2004 1993 1993 1993 1993 1993 1994
Duration in Hours 341.08 555.28 71.17 54.00 27.00 48.00 39.67 172.58 32.88 993.00 523.45 200.00 30.08 148.08 104.00 117.65 68.68 150.42 155.38 43.87 111.00 57.00 214.00 236.65 890.12 112.33 133.93 28.68 34.92 672.00 1517.10 99.38 40.83 416.58 34.58 159.92 37.87 201.42 127.42 41.25 498.72 952.00 566.00 113.03 92.48 104.00 368.58 1224.58 3632.23 24.52 41.85 27.50 159.65 616.00 305.47 80.00 55.98 238.00 33.50 944.00 27.00 33.25 264.23 264.23 131.13 1099.03
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06
Forced State Outage Code Type State Description 12 Operating under a forced derating 21 1 Sudden Forced Outage 25 Preventive Maintenance Outage 24 12 25 23 12 12 21 12 24 25 25 12 12 12 24 12 21 12 24 24 25 16 24 25 24 21 24 24 24 24 21 12 12 12 12 12 25 23 21 25 23 24 16 24 22 22 24 12 25 24 24 25 25 13 12 12 12 25 24 21 24 Corrective Maintenance Outage Operating under a forced derating Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Sudden Forced Outage Operating under a forced derating Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Corrective Maintenance Outage Operating under a forced derating Deferable Forced Outage Operating under a forced derating Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Available but not Operating under a planned derating Corrective Maintenance Outage Preventive Maintenance Outage Corrective Maintenance Outage Starting Failure Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Sudden Forced Outage Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Starting Failure Preventive Maintenance Outage Forced Extention of a Preventive Maintenance Outage Corrective Maintenance Outage Available but not Operating under a planned derating Corrective Maintenance Outage Forced Extention of a Corrective Maintenance Outage Forced Extention of a Corrective Maintenance Outage Corrective Maintenance Outage Operating under a forced derating Preventive Maintenance Outage Corrective Maintenance Outage Corrective Maintenance Outage Preventive Maintenance Outage Preventive Maintenance Outage Operating under a schedualed derating Operating under a forced derating Operating under a forced derating Operating under a forced derating Preventive Maintenance Outage Corrective Maintenance Outage Imediately Deferable Forced Outage Corrective Maintenance Outage
Sync Cond Code
1
3
4
1
4
2
Common Mode Capacity Outage During Code State 110 0 0 0 0 81 0 0 0 125 91 0 133 0 0 0 110 90 110 0 120 0 120 0 0 0 80 0 0 0 0 0 0 0 0 0 40 1 142 1 136 1 140 110 0 0 0 1 0 0 0 110 0 0 0 0 110 0 0 0 1 0 0 110 155 130 150 1 0 0 0 0
Start Date-Time 1994-10-17 05:30 1994-10-18 15:00 1994-10-23 11:20 1994-10-23 11:20 1995-01-02 20:20 1995-02-17 14:20 1995-06-30 19:00 1995-06-30 19:00 1995-07-21 16:00 1995-08-17 17:06 1995-09-05 12:15 1995-10-14 20:27 1995-10-15 21:13 1996-05-09 08:00 1996-06-01 00:01 1997-01-27 08:00 1997-06-18 09:10 1997-06-30 13:35 1997-07-31 16:00 1997-08-09 00:33 1997-09-03 10:45 1997-09-08 13:25 1997-09-09 22:10 1997-10-22 00:00 1997-11-06 08:00 1997-12-01 08:00 1997-12-05 03:00 1998-01-27 16:00 1998-02-01 08:00 1998-03-06 08:00 1998-03-14 11:00 1998-04-20 08:00 1998-05-03 02:00 1998-05-06 11:00 1998-05-24 08:13 1998-06-26 18:12 1998-07-27 08:50 1998-08-02 00:00 1998-08-19 06:00 1998-08-21 06:00 1998-10-19 07:00 1998-11-09 07:08 1999-01-01 00:00 1999-02-21 14:00 1999-04-01 16:00 1999-04-10 00:00 1999-05-05 08:00 1999-06-10 08:00 1999-08-06 08:00 1999-08-16 16:00 1999-08-23 03:06 1999-09-21 08:00 1999-10-14 09:42 1999-11-23 08:00 2000-04-24 05:58 2000-06-16 22:54 2000-10-17 05:20 2000-10-24 00:01 2000-10-28 01:35 2000-12-13 05:54 2000-12-31 12:00 2001-04-01 00:01 2001-04-23 07:00 2001-05-02 20:00 2001-05-09 12:18 2001-06-08 08:00
Finish Date-Time 1994-10-18 15:00 1994-10-19 19:50 1994-11-14 11:00 1994-11-14 11:00 1995-01-06 17:25 1995-02-18 16:00 1995-07-21 16:00 1995-07-21 16:00 1995-08-16 14:10 1995-08-19 16:15 1995-09-07 16:30 1995-10-15 21:13 1995-10-19 04:19 1996-06-01 00:01 1996-09-08 03:33 1997-06-18 09:10 1997-06-20 11:02 1997-07-03 09:59 1997-08-01 20:00 1997-08-12 05:55 1997-09-08 13:25 1997-09-09 22:10 1997-10-02 16:00 1997-10-31 13:40 1997-11-21 16:00 1997-12-05 03:00 1997-12-09 16:00 1998-02-01 08:00 1998-03-06 07:59 1998-03-14 11:00 1998-03-16 05:50 1998-04-22 01:30 1998-05-05 23:10 1998-05-08 00:00 1998-05-25 23:15 1998-07-01 14:35 1998-07-30 08:00 1998-08-04 06:00 1998-08-21 06:00 1998-08-23 06:00 1998-10-20 21:00 1999-01-01 00:00 1999-02-21 14:00 1999-02-24 14:07 1999-04-10 00:00 1999-04-11 12:00 1999-05-07 16:00 1999-06-11 16:00 1999-08-16 16:00 1999-08-20 23:00 1999-09-12 04:00 1999-09-28 19:00 1999-10-15 22:55 1999-12-10 08:30 2000-05-06 16:00 2000-08-21 09:07 2000-10-24 00:00 2000-10-27 19:53 2000-11-10 17:05 2000-12-31 12:00 2001-01-06 02:00 2001-04-23 04:55 2001-05-02 20:00 2001-05-03 22:45 2001-05-11 05:08 2001-06-10 18:55
Outage Code 43200 64200 41100 42100 41700 43100 41100 42100 41160 31000 31000 71000 43100 31000 41100 32100 43200 43200 43200 41100 43260 42500 43260 42300 31240 99999 32310 42100 41100 33100 41100 41140 31270 31270 31270 42111 07110 07210 07210 07210 43200 63900 63900 41100 31240 31570 31280 43200 42300 42112 42112 42112 64300 31000 71190 42100 99999 31000 43260 48200 48200 31150 72000 31150 52140 41540
Outage Component Amp. Outage Code Type P P P I L P P F A A F L I I I I M P P
X M M
I V
E E E E
V
M
X
Comments UNIT RESTRICTED TO 110 MW INST. TECH KICKED 94-B TR UNIT SHUT DOWN FOR ANNUAL UNIT SHUT DOWN FOR ANNUAL A" IP INTERCEPTOR VALVE S UNIT IS IN SERVICE FOR GE UNIT IS ON ANNUAL OVERHAU UNIT IS ON ANNUAL OVERHAU FORCED EXTENSION OF OVERH 125MW BOILER PRESSURE RES BOILER WATER RESTRICTION WEST CW PUMP DISCH HEADER UNIT RESTRICTED TO 133MW MAINTENANCE WORK ON BOILE TURBINE INSPECTION AND RE INSTALL SCR MODIFICATION "B" Boiler feed pump O.O. "B" boiler FW Pp arc v/v Inspect "A" F.W. Pp arc v Repair various valves ass Forced Derate; Boiler Fee Forced Outage; Generator Forced Derate; Boiler Fee Maintenance Outage; Gener Maintenance Outage; Main Fuel supply line outage ( Stand-by; "B" FD Fan re Maintenance Outage; Gener Planned Outage; Turbine b Maintenance outage; Main Starting Failure; Turbine Maint. Outage; LP X-over Maint. Outage for test fl Maint. Outage for test fl Maint. Outage for test fl Forced Outage; Generator Forced Derate; Regional A Forced derate; Cooling wa Forced derate; CW permit Forced derate; CW permit Forced derate; "A" BFP Au Planned Outage; Burner Ma Forced Extension of Planned Outage; Burner Managemen Forced Extension of Planned Outage; Turbine #4 brg. Planned outage; Main gas isolator replacement M.O.; Safety valves repair M.O. Pilot gas igniters repair Stand-by; Scheduled derate for BFP "A" ARC valve rep Maintenance outage; H2 system modifications Forced Outage; Generator H2 leak Forced Outage; Generator H2 leak Maint. outage; Generator H2 seal repairs Operating, forced derate; "B" BFP protection fault Planned Outage; Annual Inspection CW outlet duct cleaning Maint. Outage; Generator repairs Planned outage; Natural Gas supply outage Planned Outage; Annual inspection and maintenance Operating, S/D; "B" BFP fluid coupling overhaul Operating, forced Derate; HP heater drain piping lea Operating, forced Derate; HP heater drain piping lea Operating; F.D.; Air Heaters blockage Planned Outage; Stn FW system inspect / repair Maint. Outage; Air preheaters repairs Forced Outage; Excitation XFMR bushing fail M.O., Turbine Gland drains repair
Year 1994 1994 1994 1994 1995 1995 1995 1995 1995 1995 1995 1995 1995 1996 1996 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 1999 2000 2000 2000 2000 2000 2000 2000 2001 2001 2001 2001 2001
Duration in Hours 33.50 28.83 527.67 527.67 93.08 25.67 501.00 501.00 622.17 47.15 52.25 24.77 79.10 544.02 2379.53 3409.17 49.87 68.40 28.00 77.37 122.67 32.75 545.83 229.67 368.00 91.00 109.00 112.00 791.98 195.00 42.83 41.50 69.17 37.00 39.03 116.38 71.17 54.00 48.00 48.00 38.00 1264.87 1238.00 72.12 200.00 36.00 56.00 32.00 248.00 103.00 480.90 179.00 37.22 408.50 298.03 1570.22 162.67 91.87 327.50 438.10 134.00 532.90 229.00 26.75 40.83 58.92
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00
Station ID BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT BUT
Unit No 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06 06
Forced State Outage Code Type State Description 24 Corrective Maintenance Outage 13 Operating under a schedualed derating 21 4 Starting Failure 12 Operating under a forced derating 12 Operating under a forced derating 25 Preventive Maintenance Outage 25 Preventive Maintenance Outage 25 Preventive Maintenance Outage 12 Operating under a forced derating 12 Operating under a forced derating 13 Operating under a schedualed derating 12 Operating under a forced derating 21 1 Sudden Forced Outage 12 Operating under a forced derating 15 Available but not Operating under a forced derating 12 Operating under a forced derating 15 Available but not Operating under a forced derating 12 Operating under a forced derating 15 Available but not Operating under a forced derating 15 Available but not Operating under a forced derating 15 Available but not Operating under a forced derating 12 Operating under a forced derating 15 Available but not Operating under a forced derating 24 Corrective Maintenance Outage 15 Available but not Operating under a forced derating 15 Available but not Operating under a forced derating 24 Corrective Maintenance Outage 15 Available but not Operating under a forced derating 12 Operating under a forced derating 12 Operating under a forced derating 12 Operating under a forced derating 15 Available but not Operating under a forced derating 15 Available but not Operating under a forced derating 25 Preventive Maintenance Outage 25 Preventive Maintenance Outage 25 Preventive Maintenance Outage 24 Corrective Maintenance Outage 25 Preventive Maintenance Outage 24 Corrective Maintenance Outage 24 Corrective Maintenance Outage
Sync Cond Code
Common Mode Capacity Outage During Code State 0 80 0 148 148 0 0 0 150 150 80 150 0 150 150 150 150 150 150 150 150 155 155 0 155 155 0 155 155 110 155 155 155 0 1 0 1 0 1 0 0 0 0
Start Date-Time 2001-10-05 07:52 2001-10-18 08:20 2001-11-06 14:06 2001-12-01 00:01 2001-12-19 15:00 2001-12-21 00:39 2002-03-29 17:17 2002-04-06 18:15 2002-04-08 12:50 2002-04-13 22:00 2002-04-15 18:15 2002-04-18 16:00 2002-04-24 15:14 2002-05-03 09:20 2002-05-10 08:20 2002-05-13 13:45 2002-05-15 09:28 2002-05-16 12:45 2002-05-24 09:13 2002-05-28 09:00 2002-05-30 15:14 2002-07-09 10:20 2002-07-16 17:45 2002-07-29 08:30 2002-07-30 18:00 2002-08-07 20:00 2002-09-02 20:45 2002-09-06 07:00 2002-09-16 08:50 2002-09-18 16:06 2002-09-20 13:05 2002-09-21 16:28 2002-09-25 16:40 2002-11-01 08:00 2003-05-11 08:00 2003-05-14 16:01 2003-05-17 00:00 2003-09-15 00:00 2003-12-05 16:00 2003-12-12 16:01
Finish Date-Time 2001-10-09 16:00 2001-10-23 12:00 2001-11-08 00:00 2001-12-19 13:00 2001-12-21 00:39 2002-03-29 11:47 2002-04-01 12:51 2002-04-08 12:50 2002-04-13 04:38 2002-04-15 08:00 2002-04-17 01:35 2002-04-24 15:14 2002-05-02 12:52 2002-05-10 08:20 2002-05-13 13:45 2002-05-15 09:28 2002-05-16 12:45 2002-05-24 09:13 2002-05-27 14:10 2002-05-30 10:25 2002-07-09 04:05 2002-07-16 17:45 2002-07-29 08:30 2002-07-30 18:00 2002-08-07 00:00 2002-09-02 20:45 2002-09-06 07:00 2002-09-16 08:50 2002-09-18 16:06 2002-09-20 08:00 2002-09-21 16:28 2002-09-25 05:15 2002-11-01 08:00 2002-11-22 16:00 2003-05-14 16:00 2003-05-17 00:00 2003-05-26 22:00 2003-10-24 16:17 2003-12-12 16:00 2003-12-19 16:00
Outage Code 41540 32310 63900 31150 31150 63100 63100 63100 31150 31150 32310 31150 65100 31150 31150 31150 31150 31150 31150 31150 31150 31150 31150 51120 31150 31150 42300 31150 31150 43200 31150 31150 31150 31000 76000 71190 71190 42200 48100 42111
Outage Component Amp. Outage Code Type
P
I
I
Comments Maint. Outage; HP gland drain piping repair Operating, scheduled derate; FD fan bearing repair Start Failure; BMS purge problems Operating, F.D.; Furnace pressure high Operating, F.D.; Furnace pressure high Planned outage; DCS install Planned outage; DCS install Planned outage; DCS install DCS commissioning; Forced de-rate furnace pressure DCS commissioning; Forced de-rate furnace pressure Sched. De-rate FD fan vibration DCS commissioning; Forced de-rate furnace pressure FO; MODS opened under load: demolition contractor DCS commissioning; Forced de-rate furnace pressure ABNO(FD); Furnace Pressure derate O(FD); Furnace Pressure ABNO(FD); Furnace Pressure derate O(FD); Furnace Pressure ABNO(FD); Furnace Pressure derate ABNO(FD); Furnace Pressure derate ABNO(FD); Furnace Pressure derate O(FD); Furnace Pressure derate ABNO(FD); Furnace Pressure derate MO; T6 repair ABNO(FD); Furnace Pressure derate ABNO(FD); Furnace Pressure derate MO; Top East H2 cooler gasket leak ABNO(FD); Furnace Pressure derate O(FD); Furnace pressure derate O(FD); BFP "A" oil cooler leak O(FD); Furnace pressure derate ABNO(FD); Furnace Pressure derate ABNO(FD); Furnace Pressure derate PO; Annual Inspection PO; NH3 Storage Facility upgrade PO; CW OUTLET DUCT INSPECTION MO; CW Outlet duct repair PO; AVR Upgrade to 24. Unit not on line prior to outage.) MO; Generator beraring inspection
Year 2001 2001 2001 2001 2001 2001 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2003 2003 2003 2003 2003 2003
Duration in Hours 104.13 123.67 33.90 444.98 33.65 2363.13 67.57 42.58 111.80 34.00 31.33 143.23 189.63 167.00 77.42 43.72 27.28 188.47 76.95 49.42 948.85 175.42 302.75 33.50 174.00 624.75 82.25 241.83 55.27 39.90 27.38 84.78 879.33 512.00 80.00 55.98 238.00 952.28 168.00 167.98
Report Start date 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00 1993-04-01 00:00
Report Finish Date 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00 2004-03-01 00:00