WAC 463-85-230
Emissions and electrical production
monitoring, recordkeeping and reporting requirements. (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 CFR Sections
75.10 and 75.13 and 40 CFR Part 75 Appendix F. If allowed by
the requirements of 40 CFR Part 72, a facility may estimate CO2
emissions through fuel carbon content monitoring and methods
meeting the requirements of 40 CFR Sections 75.10 and 75.13
and 40 CFR Part 75 Appendix G.
(B) When the monitoring data from a continuous emission
monitoring system does not meet the completeness requirements
of 40 CFR Part 75, the baseload electric generation facility
operator or operator will substitute data according to the
process in 40 CFR Part 75.
(C) Continuous emission monitors for CO2 will be installed
at a location meeting the requirements of 40 CFR Part 75,
Appendix A. The CO2 and flow monitoring equipment must meet
the quality control and quality assurance requirements of 40
CFR 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.
(2) Reporting requirements. The results of the
monitoring required by this section shall be reported to EFSEC
and ecology annually.
(a) Facilities or units subject to the reporting
requirements of 40 CFR Part 75. Annual emissions of CO2, N2O
and CH4 will be reported to ecology and EFSEC by January 31 of
each calendar year for emissions that occurred in the previous
calendar year. The report may be an Excel™ or CSV format copy
of the report submitted to EPA per 40 CFR Part 75 with the
emissions for N2O and CH4 appended to the report.
(b) For facilities or units not subject to the reporting
requirements of 40 CFR Part 75, annual emissions of CO2, N2O
and CH4 and supporting information will be reported to ecology
and the air quality permitting authority with jurisdiction
over the facility by January 31 of each calendar year for
emissions that occurred in the previous calendar year.
[Statutory Authority: Chapters 80.70 and 80.80 RCW and RCW 80.50.040. 08-14-064, § 463-85-230, filed 6/25/08, effective
7/26/08.]