Washington Administrative Code › Title 173 - Ecology, Department of (See also Titles 197, 317, 372, and 508) › Chapter 173-407 - GREENHOUSE GAS MITIGATION REQUIREMENTS AND EMISSIONS PERFORMANCE STANDARD FOR POWER PLANTS › Part II - GREENHOUSE GAS EMISSIONS PERFORMANCE STANDARD AND SEQUESTRATION PLANS AND PROGRAMS › Section 173-407-160 - Emissions and electrical production monitoring, recordkeeping and reporting requirements under Part II

Current through Register Vol. 24-14, July 15, 2024
(1)
				Monitoring and recordkeeping requirements. A baseload electric generation
				facility or unit and baseload electric cogeneration facility or unit required
				to meet GHG EPS in WAC
				173-407-130
				must monitor and report the following parameters as explained below:
(a) Electrical output in MWh: Electrical
				output as measured at the point of connection with the local electrical
				distribution network or transmission line, as appropriate. The facility will
				measure on an hourly or daily basis and the measurements in a form suitable for
				calculations to determine compliance with GHG EPS;
(b) Useful thermal energy output in
				MWHeq: Quantity of energy supplied to nonelectrical
				production determined by monitoring both the energy supplied and the unused
				energy returned by the thermal energy user or uses. The facility can accomplish
				required monitoring 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) Each facility will measure on an hourly
				or daily basis and record the measurements in a form suitable for calculations
				to determine compliance with the GHG EPS.
(c) Regulated GHG emissions.
(i) The regulated GHG emissions are the
				emissions of regulated GHG from the main plant exhaust stack and any bypass
				stacks or flares. A facility or unit using CO2 controls
				and sequestration to comply with the GHG EPS must include direct and fugitive
				CO2 emissions from the CO2
				separation and compression process.
(ii) Carbon dioxide.
(A) A facility or unit subject to WAC
				173-407-130,
				with a net output rating of 25 MW or more of electricity, must monitor
				CO2 emissions by a continuous emission monitoring system
				meeting the requirements of
				40 C.F.R.
				75.10 and
				75.13
				and 40 C.F.R. Part 75, Appendix F, except under (c)(i)(A)(I) and (II) of this
				subsection (federal rules in effect on the date in WAC 173-407-006):
(I) 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.
				75.10 and
				75.13
				and 40 C.F.R. Part 75, Appendix G (federal rules in effect on the date in WAC
				173-407-006).
(II) If the annual
				heat input to the electric generation facility is less than 90 percent fossil
				fuel, ecology may approve the use of emission factors in 40 C.F.R. Part 98,
				Table C-1 (in effect on the date in WAC 173-407-006).
(B) A facility or unit subject to WAC
				173-407-130,
				with a net output of less than 25 MW of electricity, must use one of the
				following three methods:
(I) Continuous
				emission monitoring system meeting the requirements of
				40 C.F.R.
				75.10 and
				75.13
				and 40 C.F.R. Part 75, Appendix F (federal rules in effect on the date in WAC
				173-407-006);
(II) Fuel carbon
				content monitoring and methods meeting the requirements of
				40 C.F.R.
				75.10 and
				75.13
				and 40 C.F.R. Part 75, Appendix G (federal rules in effect on the date in WAC
				173-407-006); or
(III) Emission
				factors in 40 C.F.R. Part 98, Table C-1 (in effect on the date in WAC
				173-407-006).
(C) When
				the monitoring data from a continuous emission monitoring system does not meet
				the completeness requirements of 40 C.F.R. Part 75, Subpart D, the facility
				owner or operator must substitute data according to the process in  40 C.F.R.
				Part 75, Appendix C (in effect on the date in WAC 173-407-006).
(D) A facility or unit must install
				continuous emission monitors for CO2 under (c)(ii) of
				this subsection 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 (in effect on the date in WAC 173-407-006).
(iii) Nitrous oxide
				(N2O).
(A) A facility
				or unit that triggers the applicability in WAC
				173-407-120
				prior to March 24, 2018, and produces 25 MW or more of electricity must
				determine the N2O emissions as follows:
(I) For the first year of operation, facility
				owner or operator will estimate N2O emissions using the
				emission factors from 40 C.F.R. Part 98, Table C-2 or other authoritative
				source as approved by ecology.
(II)
				For succeeding years, facility operator or owner will estimate
				N2O emissions using generating unit specific emission
				factors derived from emissions testing using ecology or EPA approved methods.
				Facility owner or operator must derive the emission factor 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.
(B) A facility or unit that triggers the
				applicability in WAC
				173-407-120
				prior to March 24, 2018, and produces less than 25 MW of electricity will
				estimate the annual N2O emissions by the emission
				factors from 40 C.F.R. Part 98, Table C-2 or other authoritative source as
				approved by ecology.
(C) A facility
				or unit required to develop a generating unit specific
				N2O emission factor prior to March 24, 2018, must
				estimate N2O emissions using the generating unit
				specific emission factor.
(D) Any
				facility or unit that triggers the applicability in WAC
				173-407-120
				on or after March 24, 2018, must estimate N2O emissions
				using one of the following emission factors:
(I) Generating unit specific emission factor
				derived through emissions testing following the schedule in (c)(iii)(A) of this
				subsection;
(II) Emission factor
				from 40 C.F.R. Part 98, Table C-2; or
(III) Other emission factor from
				authoritative sources as approved by ecology.
(iv) Methane (CH4).
(A) A facility or unit that triggers the
				applicability in WAC
				173-407-120
				prior to March 24, 2018, and produces 25 MW or more of electricity must
				determine the CH4 emissions as follows:
(I) For the first year of operation, the
				facility owner or operator will estimate CH4 emissions
				using the emission factors from 40 C.F.R. Part 98, Table C-2 or other
				authoritative source as approved by ecology.
(II) For succeeding years, the facility owner
				or operator will estimate CH4 emissions using generating
				unit specific emission factors derived from emissions testing using ecology or
				EPA approved methods. The facility owner or operator must derive the emission
				factor 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.
(B) A facility or unit that triggers the
				applicability in WAC
				173-407-120
				prior to March 24, 2018, and produces less than 25 MW of electricity will
				estimate the annual CH4 emissions by the emission
				factors from 40 C.F.R. Part 98, Table C-2 or other authoritative source as
				approved by ecology.
(C) A facility
				or unit required to develop a generating unit specific
				CH4 emission factor prior to March 24, 2018, must
				estimate CH4 emissions using the generating unit
				specific emission factor.
(D) Any
				facility or unit that triggers the applicability in WAC
				173-407-120
				on or after March 24, 2018, must estimate CH4 emissions
				using one of the following emission factors:
(I) Generating unit specific emission factor
				derived through emissions testing following the schedule in (c)(iv) (A) of this
				subsection;
(II) Emission factor
				from         40 C.F.R. Part 98, Table C-2; or
(III) Other emission factor from
				authoritative sources as approved by ecology.
(d) Fuel usage and heat content
				information.
(i) Facility owner and operator
				must monitor fossil fuel usage by measuring continuous fuel volume or weight as
				appropriate for the fuel used. Facility owner and operator must measure on an
				hourly or daily basis and record the measurements in a form suitable for use in
				calculating GHG emissions.
(ii)
				Facility owner or operator must monitor renewable fuel usage by measuring
				continuous fuel volume or weight as appropriate for the fuel used. Facility
				owner or operator must measure on an hourly or daily basis and record the
				measurements in a form suitable for use in calculating GHG emissions.
(iii) Facility owner or operator must monitor
				renewable fuel feedstocks by measuring the fuel volume or weight, as
				appropriate, as the feedstocks are used in the combustion process. Facility
				owner or operator must measure on an hourly or daily basis and record the
				measurements in a form suitable for use in calculating GHG emissions.
(iv) Facility owner or operator must monitor
				renewable resources used in the production of electricity continuously by a
				method approved by ecology to determine heat input to the electric generation
				process.
(v) Facility owner or
				operator must test heat content of fossil fuels at least once per calendar
				year. The owner or operator of the facility or unit must submit a proposed fuel
				content monitoring program to ecology for approval. Upon request and submission
				of appropriate documentation of fuel heat content variability, ecology may
				allow a source to:
(A) Test the heat content
				of the fossil fuel less often than once per year; or
(B) Use the representative heat content for
				the fuel instead of the periodic monitoring of heat content.
(vi) Facility owner or operator
				must test renewable fuel heat content monthly or with a different frequency
				approved by ecology. The facility owner or operator must base the different
				frequency on the variability of the heat content of the renewable fuel.
(A) If a facility or unit using a mixture of
				renewable and fossil fuels does not adjust their GHG emissions by accounting
				for the heat input from renewable fuels, ecology does not require monitoring of
				the heat content of the renewable fuels.
(B) Upon request and with appropriate
				documentation, ecology may allow a source to use representative heat content
				for the renewable fuel instead of the periodic monitoring of heat content
				required above.
(vii)
				Facility owner or operator must test the heat content of renewable fuel
				feedstocks monthly or on a different schedule approved by ecology. Ecology will
				approve the different schedule based on the variability of the heat content of
				the renewable fuel feedstocks. The facility owner or operator must measure the
				heat content of the fuel feedstocks in the form they are used in the combustion
				process.
(A) If a facility or a unit using a
				mixture of renewable and fossil fuels and does not adjust their GHG emissions
				by accounting for the heat input from renewable fuels, ecology does not require
				monitoring of the heat content of the renewable fuel feedstocks.
(B) Upon request and with supporting
				documentation, ecology may allow a source to use representative heat content
				for the renewable fuel feedstock instead of the periodic monitoring of heat
				content required above.