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

Current through Register Vol. 24-14, July 15, 2024
(1) Monitoring and recordkeeping requirements. For all baseload
				electric generation facilities or units and baseload electric cogeneration
				facilities or units subject to WAC
				463-85-120, the following
				parameters shall be monitored and reported as explained below:
(a) Electrical output: Electrical output as measured at the
				point of connection with the local electrical distribution network or
				transmission line, as appropriate. Measurement will be on an hourly or daily
				basis and recorded in a form suitable for use in calculating compliance with
				the greenhouse gases emissions performance standard;
(b) Useful thermal energy output: Quantity of energy supplied
				to nonelectrical production uses determined by monitoring both the energy
				supplied and the unused energy returned by the thermal energy user or uses. The
				required monitoring can be accomplished through:
(i) Measurement of the mass, pressure, and temperature of the
				supply and return streams of the steam or thermal fluid; or
(ii) Use of thermodynamic calculations as approved by
				ecology.
(iii) Measurements will be on an hourly or daily basis and
				recorded in a form suitable for use in calculating compliance with the
				greenhouse gases emissions performance standard; and
(c) Regulated greenhouse gases emissions.
(i) The regulated greenhouse gases emissions are the emissions
				of regulated greenhouse gases from the main plant exhaust stack and any bypass
				stacks or flares. For baseload electric generation facilities or units and
				baseload electric cogeneration facilities or units utilizing
				CO2 controls and sequestration to comply with the
				greenhouse gases emissions performance standard, direct and fugitive
				CO2 emissions from the CO2
				separation and compression process are included.
(ii) Carbon dioxide (CO2).
(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.
(iii) Nitrous oxide (N2O). For baseload
				electric generation facilities or units or baseload electric cogeneration
				facilities or units subject to WAC
				463-85-120 producing 350 MW or
				more of electricity, N2O emissions shall be determined
				as follows:
(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.
(iv) Methane (CH4). For baseload
				electric generation facilities or units or baseload electric cogeneration
				facilities or units subject to WAC
				173-407-120 producing 350 MW or
				more of electricity, CH4 emissions shall be determined
				as follows:
(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.
(d) Fuel usage and heat content information.
(i) Fossil fuel usage will be monitored by measuring continuous
				fuel volume or weight as appropriate for the fuel used. Measurement will be on
				an hourly or daily basis and recorded in a form suitable for use in calculating
				greenhouse gases emissions.
(ii) Renewable energy fuel usage will be monitored by measuring
				continuous fuel volume or weight as appropriate for the fuel used. Measurement
				will be on an hourly or daily basis and recorded in a form suitable for use in
				calculating greenhouse gases emissions.
(iii) Heat content of fossil fuels shall be tested at least
				once per calendar year. The owner or operator of the baseload electric
				generation facility or unit shall submit a proposed fuel content monitoring
				program to EFSEC for EFSEC's approval. Upon request and submission of
				appropriate documentation of fuel heat content variability, EFSEC may allow a
				source to:
(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.
(iv) Renewable energy fuel heat content will be tested monthly
				or with a different frequency approved by EFSEC. A different frequency will be
				based on the variability of the heat content of the renewable energy
				fuel.
(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.