Washington Administrative Code
Title 463 - Energy Facility Site Evaluation Council
Chapter 463-85 - Greenhouse gases emissions performance standard and sequestration plans and programs for baseload electric generating facilities
Section 463-85-230 - Emissions and electrical production monitoring, recordkeeping and reporting requirements

(A) For baseload electric generation facilities or units and baseload electric cogeneration facilities or units subject to WAC 463-85-120, producing 350 MW or more of electricity, CO2 emissions will be monitored by a continuous emission monitoring system meeting the requirements of 40 C.F.R. Sections 75.10 and 75.13 and 40 C.F.R. Part 75 Appendix F. If allowed by the requirements of 40 C.F.R. Part 72, a facility may estimate CO2 emissions through fuel carbon content monitoring and methods meeting the requirements of 40 C.F.R. Sections 75.10 and 75.13 and 40 C.F.R. Part 75 Appendix G.

(B) When the monitoring data from a continuous emission monitoring system does not meet the completeness requirements of 40 C.F.R. Part 75, the baseload electric generation facility operator or operator will substitute data according to the process in 40 C.F.R. Part 75.

(C) Continuous emission monitors for CO2 will be installed at a location meeting the requirements of 40 C.F.R. Part 75, Appendix A. The CO2 and flow monitoring equipment must meet the quality control and quality assurance requirements of 40 C.F.R. Part 75, Appendix B.

(A) For the first year of operation, N2O emissions are estimated by use of emission factors as published by the Environmental Protection Agency, the federal Department of Energy's Energy Information Agency, or other authoritative source as approved by ecology for use by the facility.

(B) For succeeding years, N2O emissions will be estimated through use of generating unit specific emission factors derived through use of emissions testing using ecology or Environmental Protection Agency approved methods. The emission factor shall be derived through testing N2O emissions from the stack at varying loads and through at least four separate test periods spaced evenly throughout the first year of commercial operation.

(A) For the first year of operation, CH4 emissions are estimated by use of emission factors as published by the Environmental Protection Agency, the federal Department of Energy's Energy Information Agency, or other authoritative source as approved by ecology for use by the facility.

(B) For succeeding years, CH4 emissions will be estimated through use of plant specific emission factors derived through use of emissions testing using ecology or Environmental Protection Agency approved methods. The emission factor shall be derived through testing CH4 emissions from the stack at varying loads and through at least four separate test periods spaced evenly through the first year of commercial operation.

(A) Test the heat content of the fossil fuel less often than once per year; or

(B) Utilize representative heat content for the renewable energy source instead of the periodic monitoring of heat content required above.

(A) If the baseload electric generation facilities or units or baseload electric cogeneration facilities or units subject to WAC 463-85-120 using a mixture of renewable and fossil fuels do not adjust their greenhouse gases emissions by accounting for the heat input from renewable energy fuels, monitoring of the heat content of the renewable energy fuels is not required.

(B) Upon request and with appropriate documentation, EFSEC may allow a source to utilize representative heat content for the renewable energy source instead of the periodic monitoring of heat content required above.