Current through Register Vol. 24-06, March 15, 2024
Persons subject to the requirements of this chapter must submit
GHG reports to ecology, as specified in this section. Every metric ton of
CO2e emitted by a reporter required to report under this
chapter and covered under any applicable source category listed in WAC
173-441-120,
173-441-122, or 173-441-124 must be included in the report.
(1)
General. Follow the
procedures for emission calculation, monitoring, quality assurance, missing
data, recordkeeping, and reporting that are specified in each relevant section
of this chapter.
(2)
Schedule. The annual GHG report must be submitted as follows:
(a) Report submission due date:
(i) A person required to report or
voluntarily reporting GHG emissions under WAC
173-441-030 must
submit the report required under this chapter to ecology no later than March
31st of each calendar year for GHG emissions in the previous calendar year.
Electric power entities reporting under WAC 173-441-124 must submit a report
based on best available information by March 31st. Electric power entities
reporting under WAC 173-441-124 must submit a final revised report by June 1st
of each calendar year for GHG emissions in the previous calendar year
consistent with deadlines for electric power entities in external GHG emissions
trading programs.
(ii) Unless
otherwise stated, if the final day of any time period falls on a weekend or a
state holiday, the time period shall be extended to the next business
day.
(b) Reporting
requirements begin:
(i) For an existing
reporter that began operation before January 1, 2012, report emissions for
calendar year 2012 and each subsequent calendar year.
(ii) For a new reporter that begins operation
on or after January 1, 2012, and becomes subject to the rule in the year that
it becomes operational, report emissions beginning with the first operating
month and ending on December 31st of that year. Each subsequent annual report
must cover emissions for the calendar year, beginning on January 1st and ending
on December 31st.
(iii) For any
reporter that becomes subject to this rule because of a physical or operational
change that is made after January 1, 2012, report emissions for the first
calendar year in which the change occurs.
(A)
Reporters begin reporting with the first month of the change and ending on
December 31st of that year. For a reporter that becomes subject to this rule
solely because of an increase in hours of operation or level of production, the
first month of the change is the month in which the increased hours of
operation or level of production, if maintained for the remainder of the year,
would cause the reporter to exceed the applicable threshold.
(B) Suppliers and electric power entities
begin reporting January 1st and ending on December 31st the year of the
change.
(C) For all reporters, each
subsequent annual report must cover emissions for the calendar year, beginning
on January 1st and ending on December
31st.
(3)
Content of the annual
report. Each annual GHG report must contain the following information.
All reported information is subject to verification by ecology as described in
subsection (5) of this section.
(a) Reporter
name, reporter ID number, and physical street address of the reporter,
including the city, state, and zip code. If the facility does not have a
physical street address, then the facility must provide the latitude and
longitude representing the geographic centroid or center point of facility
operations in decimal degree format. This must be provided in a comma-delimited
"latitude, longitude" coordinate pair reported in decimal degrees to at least
four digits to the right of the decimal point.
(b) Year and months covered by the
report.
(c) Date of
submittal.
(d) For facilities,
report annual emissions of each GHG (as defined in WAC
173-441-020) and each
fluorinated heat transfer fluid, as follows:
(i) Annual emissions (including biogenic
CO2) aggregated for all GHGs from all applicable source
categories in WAC
173-441-120
and expressed in metric tons of CO2e calculated using
Equation A-1 of WAC
173-441-030(1)(b)(iii).
(ii) Annual emissions of biogenic
CO2 aggregated for all applicable source categories in
WAC
173-441-120,
expressed in metric tons.
(iii)
Annual emissions from each applicable source category in WAC
173-441-120,
expressed in metric tons of each applicable GHG listed in (d)(iii)(A) through
(F) of this subsection.
(A) Biogenic
CO2.
(B)
CO2 (including biogenic
CO2).
(C)
CH4.
(D)
N2O.
(E)
Each fluorinated GHG.
(F) For
electronics manufacturing each fluorinated heat transfer fluid that is not also
a fluorinated GHG as specified under WAC
173-441-040.
(iv) Emissions and other data for individual
units, processes, activities, and operations as specified in the "data
reporting requirements" section of each applicable source category referenced
in WAC
173-441-120.
(v) Indicate (yes or no) whether reported
emissions include emissions from a cogeneration unit located at the
facility.
(vi) When applying (d)(i)
of this subsection to fluorinated GHGs and fluorinated heat transfer fluids,
calculate and report CO2e for only those fluorinated
GHGs and fluori-nated heat transfer fluids listed in WAC
173-441-040.
(vii) For reporting year 2014 and thereafter,
you must enter into verification software specified by the director the data
specified in the verification software records provision in each applicable
record-keeping section. For each data element entered into the verification
software, if the software produces a warning message for the data value and you
elect not to revise the data value, you may provide an explanation in the
verification software of why the data value is not being revised. Whenever the
use of verification software is required or voluntarily used, the file
generated by the verification software must be submitted with the facility's
annual GHG report.
(e)
For suppliers and electric power entities, report annual emissions of each GHG
(as defined in WAC
173-441-020) as
follows:
(i) Annual emissions (including
biogenic CO2) aggregated for all GHGs from all
applicable source categories in WAC 173-441-122 and 173-441-124 and expressed
in metric tons of CO2e calculated using Equation A-1 of
WAC
173-441-030(1)(b)(iii).
(ii) Annual emissions of biogenic
CO2 aggregated for all applicable source categories in
WAC 173-441-122 and 173-441-124, expressed in metric tons.
(iii) Annual emissions from each applicable
source category in WAC 173-441-122 and 173-441-124, expressed in metric tons of
each applicable GHG listed in subsection (3)(d)(iii)(A) through (E) of this
section.
(A) Biogenic
CO2.
(B)
CO2 (including biogenic
CO2).
(C)
CH4.
(D)
N2O.
(E)
Each fluorinated GHG.
(iv) Emissions and other data for individual
units, processes, activities, and operations as specified in the "data
reporting requirements" section of each applicable source category referenced
in WAC 173-441-122 and 173-441-124.
(f) A written explanation, as required under
subsection (4) of this section, if you change emission or product data
calculation methodologies during the reporting period or since the previous
reporting period.
(g) Each data
element for which a missing data procedure was used according to the procedures
of an applicable subpart referenced in WAC
173-441-120,
173-441-122, or 173-441-124 and the total number of hours in the year that a
missing data procedure was used for each data element.
(h) A signed and dated certification
statement provided by the designated representative of the owner or operator,
according to the requirements of WAC
173-441-060(5)(a).
(i) NAICS code(s) that apply to the reporter.
NAICS codes are subject to approval by ecology.
(i) Primary NAICS code. Report the NAICS code
that most accurately describes the reporter's primary product/activity/service.
The primary product/activity/service is the principal source of revenue for the
reporter. A reporter that has two distinct products/ activities/services
providing comparable revenue may report a second primary NAICS code.
(ii) Additional NAICS code(s). Report all
additional NAICS codes that describe all product(s)/activity(s)/service(s) at
the reporter that are not related to the principal source of revenue.
(j) Legal name(s) and physical
address(es) of the highest-level United States parent company(s) of the owners
(or operators) of the reporter and the percentage of ownership interest for
each listed parent company as of December 31st of the year for which data are
being reported according to the following instruc-tions.
(i) If the reporter is entirely owned by a
single United States company that is not owned by another company, provide that
company's legal name and physical address as the United States parent company
and report 100 percent ownership.
(ii) If the reporter is entirely owned by a
single United States company that is, itself, owned by another company (e.g.,
it is a division or subsidiary of a higher-level company), provide the legal
name and physical address of the highest-level company in the ownership
hierarchy as the United States parent company and report 100 percent
ownership.
(iii) If the reporter is
owned by more than one United States company (e.g., company A owns 40 percent,
company B owns 35 percent, and company C owns 25 percent), provide the legal
names and physical addresses of all the highest-level companies with an
ownership interest as the United States parent companies and report the percent
ownership of each company.
(iv) If
the reporter is owned by a joint venture or a cooperative, the joint venture or
cooperative is its own United States parent company. Provide the legal name and
physical address of the joint venture or cooperative as the United States
parent company, and report 100 percent ownership by the joint venture or
cooperative.
(v) If the reporter is
entirely owned by a foreign company, provide the legal name and physical
address of the foreign company's highest-level company based in the United
States as the United States parent company, and report 100 percent
ownership.
(vi) If the reporter is
partially owned by a foreign company and partially owned by one or more United
States companies, provide the legal name and physical address of the foreign
company's highest-level company based in the United States, along with the
legal names and physical addresses of the other United States parent companies,
and report the percent ownership of each of these companies.
(vii) If the reporter is a federally owned
facility, report "U.S. Government" and do not report physical address or
percent ownership.
(k) An
indication of whether the facility includes one or more plant sites that have
been assigned a "plant code" by either the Department of Energy's Energy
Information Administration or by the Environmental Protection Agency's (EPA)
Clean Air Markets Division.
(l)
Facilities must report electricity information including:
(i) Total annual electricity purchased in
megawatt hours (MWh), itemized by the supplying utility or, if not obtained
from a utility, from the supplying electric power entity for each different
source of electricity. Total annual purchases must be reported separately for
each supplying utility or electric power entity.
(ii) Self-generated electricity should be
itemized separately if a facility includes an electricity generating unit as
follows:
(A) Total facility nameplate
generating capacity in megawatts (MW).
(B) Generated electricity in MWh provided or
sold to each retail provider, electricity marketer, or other reportable
end-user that is not a part of the facility, itemized by end-user.
(C) Generated electricity for on-site
industrial applications not related to electricity generation in MWh.
(m) Report fuel use or
supplied as follows:
(i) Facilities, report
each fuel combusted separately by type, quantity, and units of
measurement.
(ii) Fuel suppliers,
report:
(A) Each fuel supplied separately by
type, quantity, and units of measurement; and
(B) Separately report the quantity of each
fuel type by purpose if the fuel supplier reports that the fuel is used for one
of the purposes described in WAC 173-441-122(5)(d)(xi).
(n) Facilities, report total
annual facility product data, units of production, and specific product based
on their first primary NAICS code.
(i)
Facilities with a primary NAICS code listed in Table 050-1 of this section must
report total annual facility product data as described in Table 050-1.
Facilities may additionally report total annual facility product data as
described in Table 050-1 for any reported secondary NAICS code. Use six digit
NAICS codes when available, otherwise use the shorter NAICS codes listed below
substituting the values in the full reported six digit NAICS code for "X".
Table 050-1: Total Annual Facility Product Data
Requirements by Primary NAICS Code.
Primary NAICS Code and Sector
Definition |
Activity |
Production Metric |
112112: Cattle Feedlots |
Cattle feedlots |
Cattle head days |
211130: Natural Gas Extraction |
Natural gas extraction |
Million standard cubic feet of natural gas
extracted |
212399: All Other Nonmetallic Mineral
Mining |
Freshwater diatomite filter aids
manufacturing |
Metric tons of mineral product produced |
2211XX: Electric Power Generation, Transmission and
Distribution |
Electric power generation, transmission and
distribution |
Net megawatt hours |
221210: Natural Gas Distribution |
Natural gas distribution |
Million standard cubic feet of natural gas
distributed |
221330: Steam and Air-conditioning
Supply |
Steam supply |
Kilograms steam produced |
311213: Malt Manufacturing |
Malt manufacturing |
Metric tons of malt produced |
3114XX: Fruit and Vegetable Preserving and Specialty
Food Manufacturing |
Fruit and vegetable preserving and specialty food
manufacturing |
Metric tons of food product produced |
3115XX: Dairy Product Manufacturing |
Dairy product manufacturing |
Metric tons of dairy product produced |
311611: Animal (except poultry)
Slaughtering |
Animal (except poultry) slaughtering |
Metric tons of meat product processed |
311613: Rendering and Meat Byproduct
Processing |
Rendering and meat by-product
processing |
Metric tons of meat by-product processed |
311919: Other Snack Food
Manufacturing |
Other snack food manufacturing |
Metric tons of snack food produced |
311920: Coffee and Tea Manufacturing |
Coffee and tea manufacturing |
Metric tons of coffee and tea produced |
321XXX: Wood Product Manufacturing |
Wood product manufacturing |
Air dried (10 percent moisture) metric tons of wood
product produced |
3221XX: Pulp, Paper, and Paperboard
Mills |
Pulp, paper, and paperboard mills |
Air dried (10 percent moisture) metric tons of
produced:
* Pulp product; or
* Paper; or
* Paperboard |
322299: All Other Converted Paper Product
Manufacturing |
All other converted paper product
manufacturing |
Air dried (10 percent moisture) metric tons of
converted paper product produced |
324110: Petroleum Refineries |
Petroleum refineries |
Report all of the following:
* Facility level Subpart MM report as reported under
40 C.F.R. Part 98 ;
* Barrels of crude oil and intermediate products
received from off-site that are processed at the facility; and
* Beginning with the first emissions year after a
refinery's first turnaround after 2022, the refinery must also submit
complexity weighted barrel (CWB) as described in CARB MRR section 95113(l)(3)
as adopted by 7/1/2021. CWB supporting data must also be submitted to Ecology
as described in CARB MRR section 95113(l)(3). |
324121: Asphalt Paving Mixture and Block
Manufacturing |
Asphalt paving mixture and block
manufacturing |
Metric tons of asphalt paving mixture and block
produced |
3251XX: Basic Chemical Manufacturing |
Basic chemical manufacturing |
Metric tons of chemical produced |
325311: Nitrogenous Fertilizer
Manufacturing |
Nitric acid production |
Metric tons of nitric acid produced |
32721X: Glass and Glass Product
Manufacturing |
Glass and glass product manufacturing |
Metric tons of glass produced |
327310: Cement Manufacturing |
Cement manufacturing |
Metric tons of adjusted clinker and mineral additives
produced |
327390: Other Concrete Product
Manufacturing |
Other concrete product manufacturing |
Metric tons of concrete product produced |
327410: Lime Manufacturing |
Lime manufacturing |
Metric tons of lime produced |
327420: Gypsum Product Manufacturing |
Gypsum product manufacturing |
Metric tons of gypsum product produced |
331110: Iron and Steel Mills and Ferroalloy
Manufacturing |
Steel production using an electric arc furnace
(EAF) |
Metric tons of steel produced |
33131X: Alumina and Aluminum Production and
Processing |
Alumina and aluminum production and
processing |
Metric tons of aluminum produced |
331410: Nonferrous Metal (except aluminum) Smelting
and Refining |
Granular polysilicon production |
Metric tons of granular polysilicon
produced |
332111: Iron and Steel Forging |
Iron forging |
Metric tons of iron produced |
334413: Semiconductor and Related Device
Manufacturing |
Semiconductor and related device
manufacturing |
Square meters of mask layer produced |
335991: Carbon and Graphite Product
Manufacturing |
Carbon and graphite product
manufacturing |
Metric tons of carbon and graphite product
produced |
3364XX: Aerospace Product and Parts
Manufacturing |
Aerospace product and parts
manufacturing |
* Metric tons of aircraft product and parts produced;
or
* Square meters of external surface area of
aircraft |
486210: Pipeline Transportation of Natural
Gas |
Pipeline transportation of natural
gas |
Million standard cubic feet of natural gas
transported |
488119: Other Airport Operations |
Other airport operations |
Passenger kilometers serviced |
562111: Solid Waste Collection |
Solid waste collection |
Metric tons of total solid waste
collected |
562212: Solid Waste Landfill |
Solid waste landfill |
Metric tons of total waste entered into
landfill |
562213: Solid Waste Combustors and
Incinerators |
Solid waste combustors and
incinerators |
Net megawatt hours |
611310: Colleges, Universities, and Professional
Schools |
Colleges, universities, and professional
schools |
Students serviced |
928110: National Security |
Military bases |
Troops stationed |
(ii)
Facilities without a primary NAICS code listed in Table 050-1 of this section
must contact ecology no later than 45 calendar days prior to the emissions
report deadline established in subsection (2) of this section and report total
annual facility product data as instructed by the department. If ecology does
not identify product data for a facility, a facility must use the energy-based
calculation method described in Equation 050-1 of this section. Report product
data and inputs to the equation. Product data calculated using the energy-based
method shall use the following equation:
Product data = Sconsumed +
Fconsumed
- esold (Eq.
050-1)
Where:
"Sconsumed " is the annual amount of
steam consumed, measured in MMBtu, at the facility for any process, including
heating or cooling applications. This value shall exclude any steam used to
produce electricity. This value shall exclude steam produced from an on-site
cogeneration unit;
"Fconsumed " is the annual amount of
energy produced due to fuel combustion at the facility, measured in MMBtu. This
value shall be calculated based on measured higher heating values or the
default higher heating value of the applicable fuel in Table C-1 of 40 C.F.R.
Part 98 . This value shall include any energy from fuel combusted in an on-site
electricity generation or cogeneration unit. This value shall exclude energy to
generate the steam accounted for in the "Sconsumed " term;
"eSold" is the annual amount of
electricity sold or provided for off-site use, measured in MWh and converted to
MMBtu using the reporting year U.S. Energy Information Administration
conversion factor;
(iii)
Facilities with a change in operation that alters either their primary NAICS
code, units of production, or product data measurement method must contact
ecology no later than 45 calendar days prior to the emissions report deadline
established in subsection (2) of this section and report total annual facility
product data as instructed by the department. If ecology does not identify
product data for a facility, a facility must use the energy-based calculation
method described in Equation 050-1 of this section. Report product data and
inputs to the equation.
(iv) For a
primary NAICS code in Table 050-1 that has multiple production metrics, a
facility that wishes to change their reported production metric must contact
ecology no later than 45 calendar days prior to the emissions report deadline
established in subsection (2) of this section and report total annual facility
production data as instructed by the department.
(o) Reporters that cease operation, other
than routine maintenance or seasonal shutdowns, for more than 90 calendar days
must provide the following information:
(i)
The anticipated type of cessation: Closure or curtailment;
(ii) Date cessation began;
(iii) Date cessation ended (if applicable);
and
(iv) Reason for cessation
and/or resumption of operation.
(p) If there is an increase or decrease of
more than five percent in emissions of greenhouse gases in relation to the
previous year, the reporter must provide a brief narrative description of what
caused the increase or decrease in emissions.
(4)
Emission calculations. In
preparing the GHG report, you must use the calculation methodologies specified
in the relevant sections of this chapter. For each source category, you must
use the same calculation methodology as previous reports. This includes
throughout a reporting period, and between reporting years. An owner or
operator intending to change methodologies must provide a written explanation
at least 60 calendar days before the report submission due date in subsection
(2)(a) of this section of why a change in methodology was required. Ecology has
45 calendar days to approve or reject the change in method. The reporter must
continue to use existing methods until the change is approved by
ecology.
(5)
Verification. To verify the completeness and accuracy of reported
GHG emissions, ecology may review the certification statements described in
subsection (3)(h) of this section and any other credible evidence, in
conjunction with a comprehensive review of the GHG reports and periodic audits
of selected reporting facilities. Nothing in this section prohibits ecology
from using additional information to verify the completeness and accuracy of
the reports. Reporters must cooperate with ecology's efforts to verify GHG
reports.
(6)
Recordkeeping. A person that is required to report GHGs under this
chapter must keep records as specified in this subsection. Retain all required
records for at least 10 years from the date of submission of the annual GHG
report for the reporting year in which the record was generated. Upon request
by ecology, the person must submit the records required under this section
within 15 business days of receipt of the notification, unless a different
schedule is agreed to by ecology. Records may be retained off-site if the
records are readily available for expeditious inspection and review. For
records that are electronically generated or maintained, the equipment or
software necessary to read the records must be made available, or, if requested
by ecology, electronic records must be converted to paper documents. You must
retain the following records, in addition to those records prescribed in each
applicable section of this chapter:
(a) A list
of all units, operations, processes, and activities for which GHG emissions
were calculated.
(b) The data used
to calculate the GHG emissions for each unit, operation, process, and activity,
categorized by fuel or material type. These data include, but are not limited
to, the following information:
(i) The GHG
emissions calculations and methods used.
(ii) Analytical results for the development
of site-specific emissions factors.
(iii) The results of all required analyses
for high heat value, carbon content, and other required fuel or feedstock
parameters.
(iv) Any facility
operating data or process information used for the GHG emission
calculations.
(c) The
annual GHG reports.
(d) Missing
data computations. For each missing data event, also retain a record of the
cause of the event and the corrective actions taken to restore malfunctioning
monitoring equipment.
(e) Owners or
operators required to report under WAC
173-441-030 must
keep a written GHG monitoring plan (monitoring plan, plan).
(i) At a minimum, the GHG monitoring plan
must include the following elements:
(A)
Identification of positions of responsibility (i.e., job titles) for collection
of the emissions data.
(B)
Explanation of the processes and methods used to collect the necessary data for
the GHG calculations.
(C)
Description of the procedures and methods that are used for quality assurance,
maintenance, and repair of all continuous monitoring systems, flow meters, and
other instrumentation used to provide data for the GHGs reported under this
chapter.
(D) Facilities must
reference to one or more simplified block diagrams that provide a clear visual
representation of the relative locations and positions of measurement devices
and sampling locations, as applicable, required for calculating covered
emissions and covered product data (e.g., temperature, total pressure, HHV,
fuel consumption). The diagram(s) must include fuel sources, combustion units,
and production processes, as applicable.
(ii) The GHG monitoring plan may rely on
references to existing corporate documents (e.g., standard operating
procedures, quality assurance programs under appendix F to 40 C.F.R. Part 60 or
appendix B to 40 C.F.R. Part 75 , and other documents) provided that the
elements required by (e)(i) of this subsection are easily
recognizable.
(iii) The owner or
operator must revise the GHG monitoring plan as needed to reflect changes in
production processes, monitoring instrumentation, and quality assurance
procedures; or to improve procedures for the maintenance and repair of
monitoring systems to reduce the frequency of monitoring equipment
downtime.
(iv) Upon request by
ecology, the owner or operator must make all information that is collected in
conformance with the GHG monitoring plan available for review during an audit
within 15 business days of receipt of the notification, unless a different
schedule is agreed to by ecology. Electronic storage of the information in the
plan is permissible, provided that the information can be made available in
hard copy upon request during an audit.
(f) The results of all required certification
and quality assurance tests of continuous monitoring systems, fuel flow meters,
and other instrumentation used to provide data for the GHGs reported under this
chapter.
(g) Maintenance records
for all continuous monitoring systems, flow meters, and other instrumentation
used to provide data for the GHGs reported under this chapter.
(h) Suppliers and electric power entities
must retain any other data specified in WAC 173-441-122 and
173-441-124.
(7)
Annual GHG report revisions.
(a)
A person must submit a revised annual GHG report within 45 calendar days of
discovering that an annual GHG report that the person previously submitted
contains one or more sub-stantive errors. The revised report must correct all
substantive errors.
(b) Ecology may
notify the person in writing that an annual GHG report previously submitted by
the person contains one or more substantive errors. Such notification will
identify each such substantive error. The person must, within 45 calendar days
of receipt of the notification, either resubmit the report that, for each
identified substantive error, corrects the identified substantive error (in
accordance with the applicable requirements of this chapter) or provide
information demonstrating that the previously submitted report does not contain
the identified substantive error or that the identified error is not a
substantive error.
(c) A
substantive error is an error that impacts the quantity of GHG emissions
reported, product data reported, or otherwise prevents the reported data from
being validated or verified.
(d)
Notwithstanding (a) and (b) of this subsection, upon request by a person,
ecology may provide reasonable extensions of the 45 day period for submission
of the revised report or information under (a) and (b) of this subsection. If
ecology receives a request for extension of the 45 day period, by email, at
least five business days prior to the expiration of the 45 calendar day period,
and ecology does not respond to the request by the end of such period, the
extension request is deemed to be automatically granted for 15 more calendar
days. During the automatic 15 day extension, ecology will determine what
extension, if any, beyond the automatic extension is reasonable and will
provide any such additional extension.
(e) The owner or operator must retain
documentation for 10 years to support any revision made to an annual GHG
report.
(8)
Calibration and accuracy requirements. The owner or operator of a
facility that is subject to the requirements of this chapter must meet the
applicable flow meter calibration and accuracy requirements of this subsection.
The accuracy specifications in this subsection do not apply where either the
use of company records (as defined in WAC
173-441-020(3))
or the use of "best available information" is specified in an applicable
subsection of this chapter to quantify fuel usage and/or other parameters.
Further, the provisions of this subsection do not apply to stationary fuel
combustion units that use the methodologies in 40 C.F.R. Part 75 to calculate
CO2 mass emissions. Measurement devices used for
financial transactions between two or more independent parties meet the
calibration and accuracy requirements of this chapter.
(a) Except as otherwise provided in (d)
through (f) of this subsection, flow meters that measure liquid and gaseous
fuel feed rates, process stream flow rates, product data measuring devices, or
feedstock flow rates and provide data for the GHG emissions calculations or
product data, must be calibrated prior to January 1, 2012, for emissions data
or January 1, 2023, for product data, using the procedures specified in this
subsection when such calibration is specified in a relevant section of this
chapter. Each of these flow meters must meet the applicable accuracy
specification in (b) or (c) of this subsection. All other measurement devices
(e.g., weighing devices) that are required by a relevant subsection of this
chapter, and that are used to provide data for the GHG emissions calculations
or product data, must also be calibrated prior to January 1, 2012, for
emissions data or January 1, 2023, for product data; however, the accuracy
specifications in (b) and (c) of this subsection do not apply to these devices.
Rather, each of these measurement devices must be calibrated to meet the
accuracy requirement specified for the device in the applicable subsection of
this chapter, or, in the absence of such accuracy requirement, the device must
be calibrated to an accuracy within the appropriate error range for the
specific measurement technology, based on an applicable operating standard
including, but not limited to, manufacturer's specifications and industry
standards. The procedures and methods used to quality-assure the data from each
measurement device must be documented in the written monitoring plan, pursuant
to subsection (6)(e)(i)(C) of this section.
(i) All flow meters and other measurement
devices that are subject to the provisions of this subsection must be
calibrated according to one of the following: You may use the manufacturer's
recommended procedures; an appropriate industry consensus standard method; or a
method specified in a relevant section of this chapter. The calibration
method(s) used must be documented in the monitoring plan required under
subsection (6)(e) of this section.
(ii) For reporters that become subject to
this chapter after January 1, 2012, all flow meters and other measurement
devices (if any) that are required by the relevant subsection(s) of this
chapter to provide data for the GHG emissions calculations or product data must
be installed no later than the date on which data collection is required to
begin using the measurement device, and the initial calibration(s) required by
this subsection (if any) must be performed no later than that date.
(iii) Except as otherwise provided in (d)
through (f) of this subsection, subsequent recalibrations of the flow meters
and other measurement devices subject to the requirements of this subsection
must be performed at one of the following frequencies:
(A) You may use the frequency specified in
each applicable subsection of this chapter.
(B) You may use the frequency recommended by
the manufacturer or by an industry consensus standard practice, if no
recalibration frequency is specified in an applicable subsection.
(b) Perform all flow
meter calibration at measurement points that are representative of the normal
operating range of the meter. Except for the orifice, nozzle, and venturi flow
meters described in (c) of this subsection, calculate the calibration error at
each measurement point using Equation A-2 of this subsection. The terms "R" and
"A" in Equation A-2 must be expressed in consistent units of measure (e.g.,
gallons/minute, ft3/min). The calibration error at
each measurement point must not exceed 5.0 percent of the reference value.
Click
to view image
Where:
CE = Calibration error (%)
R = Reference value
A = Flow meter response to the reference value
(c) For orifice, nozzle, and
venturi flow meters, the initial quality assurance consists of in situ
calibration of the differential pressure (delta-P), total pressure, and
temperature transmitters.
(i) Calibrate each
transmitter at a zero point and at least one upscale point. Fixed reference
points, such as the freezing point of water, may be used for temperature
transmitter calibrations. Calculate the calibration error of each transmitter
at each measurement point, using Equation A-3 of this subsection. The terms
"R," "A," and "FS" in Equation A-3 of this subsection must be in consistent
units of measure (e.g., milliamperes, inches of water, psi, degrees). For each
transmitter, the CE value at each measurement point must not exceed 2.0 percent
of full-scale. Alternatively, the results are acceptable if the sum of the
calculated CE values for the three transmitters at each calibration level
(i.e., at the zero level and at each upscale level) does not exceed 6.0
percent.
Click
to view image
Where:
CE = Calibration error (%)
R = Reference value
A = Transmitter response to the reference value
FS = Full-scale value of the transmitter
(ii) In cases where there are only two
transmitters (i.e., differential pressure and either temperature or total
pressure) in the immediate vicinity of the flow meter's primary element (e.g.,
the orifice plate), or when there is only a differential pressure transmitter
in close proximity to the primary element, calibration of these existing
transmitters to a CE of 2.0 percent or less at each measurement point is still
required, in accordance with (c)(i) of this subsection; alternatively, when two
transmitters are calibrated, the results are acceptable if the sum of the CE
values for the two transmitters at each calibration level does not exceed 4.0
percent. However, note that installation and calibration of an additional
transmitter (or transmitters) at the flow monitor location to measure
temperature or total pressure or both is not required in these cases. Instead,
you may use assumed values for temperature and/or total pressure, based on
measurements of these parameters at a remote location (or locations), provided
that the following conditions are met:
(A) You
must demonstrate that measurements at the remote location(s) can, when
appropriate correction factors are applied, reliably and accurately represent
the actual temperature or total pressure at the flow meter under all expected
ambient conditions.
(B) You must
make all temperature and/or total pressure measurements in the demonstration
described in (c)(ii)(A) of this subsection with calibrated gauges, sensors,
transmitters, or other appropriate measurement devices. At a minimum, calibrate
each of these devices to an accuracy within the appropriate error range for the
specific measurement technology, according to one of the following: You may
calibrate using a manufacturer's specification or an industry consensus
standard.
(C) You must document the
methods used for the demonstration described in (c)(ii)(A) of this subsection
in the written GHG monitoring plan under subsection (6)(e)(i)(C) of this
section. You must also include the data from the demonstration, the
mathematical correlation(s) between the remote readings and actual flow meter
conditions derived from the data, and any supporting engineering calculations
in the GHG monitoring plan. You must maintain all of this information in a
format suitable for auditing and inspection.
(D) You must use the mathematical
correlation(s) derived from the demonstration described in (c)(ii)(A) of this
subsection to convert the remote temperature or the total pressure readings, or
both, to the actual temperature or total pressure at the flow meter, or both,
on a daily basis. You must then use the actual temperature and total pressure
values to correct the measured flow rates to standard conditions.
(E) You must periodically check the
correlation(s) between the remote and actual readings (at least once a year),
and make any necessary adjustments to the mathematical
relationship(s).
(d) Fuel billing meters are exempted from the
calibration requirements of this section and from the GHG monitoring plan and
recordkeeping provisions of subsection (6)(e)(i)(C) and (g) of this section,
provided that the fuel supplier and any unit combusting the fuel do not have
any common owners and are not owned by subsidiaries or affiliates of the same
company. Meters used exclusively to measure the flow rates of fuels that are
used for unit startup are also exempted from the calibration requirements of
this section.
(e) For a flow meter
that has been previously calibrated in accordance with (a) of this subsection,
an additional calibration is not required by the date specified in (a) of this
subsection if, as of that date, the previous calibration is still active (i.e.,
the device is not yet due for recalibration because the time interval between
successive calibrations has not elapsed). In this case, the deadline for the
successive calibrations of the flow meter must be set according to one of the
following: You may use either the manufacturer's recommended calibration
schedule or you may use the industry consensus calibration schedule.
(f) For units and processes that operate
continuously with infrequent outages, it may not be possible to meet the
deadline established in (a) of this subsection for the initial calibration of a
flow meter or other measurement device without disrupting normal process
operation. In such cases, the owner or operator may postpone the initial
calibration until the next scheduled maintenance outage. The best available
information from company records may be used in the interim. The subsequent
required recalibrations of the flow meters may be similarly postponed. Such
postponements must be documented in the monitoring plan that is required under
subsection (6)(e) of this section.
(g) If the results of an initial calibration
or a recalibration fail to meet the required accuracy specification, data from
the flow meter must be considered invalid, beginning with the hour of the
failed calibration and continuing until a successful calibration is completed.
You must follow the missing data provisions provided in the relevant missing
data sections during the period of data invalidation.
(h) Missing data substitution procedures.
Persons must comply with 40 C.F.R. Part 98 when substituting for missing data.
Substitute missing data used for product data or other data required under this
section that is not included in your 40 C.F.R. Part 98 report by using the best
available estimate of the parameter, based on all available data.
(9)
Measurement device
installation.
40
C.F.R. §
98.3(j) and 40
C.F.R. § 98.3(d) are adopted by reference as modified in WAC
173-441-120(2).
Statutory Authority: 2010 c 146, and chapters 70.235 and
70.94 RCW. 10-24-108 (Order 10-08),
§ 173-441-050, filed 12/1/10, effective
1/1/11.