Current through Register Vol. 24-06, March 15, 2024
This section establishes the scope of reportable energy and GHG
emissions under this chapter and GHG emissions calculation methods for electric
power entities. Owners and operators of electric power entities must follow the
requirements of this section to determine if they are required to report under
WAC
173-441-030(3).
Owners and operators of electric power entities that are subject to this
chapter must follow the requirements of this section when calculating
emissions. If a conflict exists between a provision in WAC
173-441-010 through
173-441-110 and
173-441-140
through
173-441-170 and any
applicable provision of this section, the requirements of those sections must
take precedence.
(1)
General
requirements. An owner or operator of an electric power entity subject
to the requirements of this chapter must report GHG emissions, including GHG
emissions from biomass, from all applicable categories listed in (a) of this
subsection using the methods and procedures in this section.
(a) Electric power entity categories:
(i) Electricity importers and exporters, as
defined in this section;
(ii)
Retail providers, including multijurisdictional retail providers, as defined in
this section;
(iii) Asset
controlling suppliers;
(iv)
Electric generating facilities in Washington state must report using the
methods specified in WAC
173-441-120.
(b) The calculation methods for voluntary
reporting in WAC
173-441-120(3)
apply, except calculation methods in WAC
173-441-120(3)(b)
take precedence over the methods from WAC
173-441-120(3)(a).
(c) Alternative calculation methods approved
by petition. An owner or operator may petition ecology to use calculation
methods other than those specified in this section to calculate its electric
power entities GHG emissions. Such alternative calculation methods must be
approved by ecology prior to reporting and must meet the requirements of WAC
173-441-140.
(2)
Definitions specific to electric
power entities. The definitions in this subsection apply throughout this
section unless the context clearly requires otherwise.
(a) "Direct delivery of electricity" means
electricity that meets any of the following criteria: The facility has a first
point of interconnection at a Washington scheduling point or within a power
system; The electricity is scheduled for delivery from the specified source to
a Washington scheduling point or a power system via a continuous physical
transmission path from interconnection of the facility in the balancing
authority in which the facility is located to the Washington scheduling point
or power system; or there is an agreement to dynamically transfer electricity
from the facility to a Washington scheduling point or power system.
(b) "Electricity generating facility" means a
facility that generates electricity and includes one or more generating units
at the same location.
(c)
"Electricity importer" means:
(i) For
electricity that is scheduled with an e-tag to a final point of delivery into a
balancing authority area located entirely within Washington state, the
electricity importer is identified on the e-tag as the purchasing-selling
entity on the last segment of the tag's physical path with the point of receipt
located outside Washington state and the point of delivery located inside
Washington state;
(ii) For
facilities physically located outside Washington state with the first point of
interconnection to a balancing authority area located entirely within
Washington state when the electricity is not scheduled on an e-tag, the
electricity importer is the facility operator or owner;
(iii) For electricity imported through a
centralized market, the electricity importer is the retail provider, marketer,
or asset controlling supplier that conducts an electricity transaction through
the EIM that results in EIM power being delivered to final point of delivery in
Washington state;
(iv) For
electricity from facilities allocated to serve retail electricity customers of
a multijurisdictional electric company, the electricity importer is the
multijurisdictional electric company;
(v) If the importer identified under (c)(i)
of this subsection is a federal power marketing administration over which
Washington state does not have jurisdiction, and the federal power marketing
administration has not voluntarily elected to comply with this chapter, then
the electricity importer is the next purchasing-selling entity in the physical
path on the e-tag, or if no additional purchasing-selling entity over which
Washington state has jurisdiction, then the electricity importer is the
electric utility that operates the Washington state transmission or
distribution system, or the generation balancing authority;
(vi) For electricity that is imported into
the state by a federal power marketing administration and sold to a public body
or cooperative customer or direct service industrial customer located in
Washington state pursuant to section 5(b) or (d) of the Pacific Northwest
Electric Power Planning and Conservation Act of 1980, P.L. 96-501, the
electricity importer is the federal marketing administration;
(vii) If the importer identified under
(c)(vi) of this subsection has not voluntarily elected to comply with this
chapter, then the electricity importer is the public body or cooperative
customer or direct service industrial customer;
(viii) For electricity that is imported into
the state to a designated scheduling point inside the balancing authority area
of a federal power marketing administration, the importer is the
purchasing-selling entity on the e-tag at the last point on the physical path
that is not the sink;
(ix) If the
importer identified under (c)(vii) of this subsection is a federal power
marketing administration that has not elected to voluntarily comply with this
chapter, then the importer is the retail provider with which the scheduling
point is associated; or
(x) For
electricity from facilities allocated to a consumer-owned utility inside
Washington state from a multijurisdictional consumer-owned utility, the
electricity importer is the consumer-owned utility inside Washington
state.
(d) "First
jurisdictional deliverer" means the owner or operator of an electric generating
facility in Washington state or an electricity importer.
(e) "Generation providing entity" or "GPE"
means a facility or generating unit operator, full or partial owner, party to a
contract for a fixed percentage of net generation from the facility or
generating unit, party to a tolling agreement with the owner, or exclusive
marketer for the facility or generating unit recognized by ecology.
(f) "Retail provider" means any of the
following:
(i) An electric utility as defined
in
RCW
19.405.020(14);
(ii) Multijurisdictional retail
providers;
(iii)
Multijurisdictional consumer-owned utilities.
(g) "Imported electricity" means electricity
generated outside Washington state with a final point of delivery within the
state.
(i) "Imported electricity" includes
electricity from an organized market, such as the energy imbalance
market.
(ii) "Imported electricity"
includes imports from linked jurisdictions, but such imports shall be construed
as having no emissions.
(iii)
Electricity from a system that is marketed by a federal power marketing
administration shall be construed as "imported electricity," not electricity
generated in Washington state.
(iv)
"Imported electricity" does not include electricity imports of unspecified
electricity that are netted by exports of unspecified electricity to any
jurisdiction not covered by a linked program by the same entity within the same
hour.
(v) For a multijurisdictional
electric company, "imported electricity" means electricity, other than from
in-state facilities, that contributes to a common system power pool. Where a
multijurisdictional electric company has a cost allocation methodology approved
by the Washington state utilities and transportation commission, the allocation
of specific facilities to Washington state's retail load will be in accordance
with that methodology.
(vi) For a
multijurisdictional consumer-owned utility, "imported electricity" includes
electricity from facilities that contribute to a common system power pool that
are allocated to a consumer-owned utility inside Washington state pursuant to a
methodology approved by the governing board of the consumer-owned
utility.
(h)
"Multijurisdictional consumer-owned utility" means an electric generation and
transmission cooperative owned by a collection of consumer-owned utilities in
multiple states or a consumer-owned utility that provides electricity to member
owners in Washington state and in one or more other states in a contiguous
service territory or from a common power system.
(i) "Multijurisdictional electric company"
means an investor-owned utility that provides electricity to customers in
Washington state and in one or more other states in a contiguous service
territory or from a common power system.
(j) "Multijurisdictional retail provider"
means a:
(i) Multijurisdictional electric
company; or
(ii)
Multijurisdictional consumer-owned utility.
(k) "E-tag" means an energy tag representing
transactions on the North American bulk electricity market scheduled to flow
between or across balancing authority areas and to and from locations listed in
an affiliated registry, as represented in a manner and form created by the
North American Electric Reliability Corporation and as maintained by the North
American Energy Standards Board or a successor organization.
(l) "Point of delivery" means a point on the
electricity transmission or distribution system where a deliverer makes
electricity available to a receiver, or available to serve load. This point may
be an interconnection with another system or a substation where the
transmission provider's transmission and distribution systems are connected to
another system, or a distribution substation where electricity is imported into
the state over a multijurisdictional retail provider's distribution
system.
(m) "Specified source of
electricity" or "specified source" means a facility, unit, or asset controlling
supplier that is permitted to be claimed as the source of electricity
delivered. The reporting entity must have either full or partial ownership in
the facility or a written power contract to procure electricity generated by
that facility or unit or from an asset controlling supplier at the time of
entry into the transaction to procure electricity.
(n) "Unspecified source of electricity" or
"unspecified source" means a source of electricity that is not a specified
source at the time of entry into the transaction to procure
electricity.
(o) "Electricity
exporter" means electric power entities that deliver exported electricity. The
entity that exports electricity is identified on the e-tag as the
purchasing-selling entity (PSE) on the last segment of the tag's physical path,
with the point of receipt located inside Washington state and the point of
delivery located outside Washington state. For electricity that is exported
from a designated scheduling point in the balancing authority area of a federal
power marketing administration, the exporter is the purchasing-selling entity
at the first point of the physical path of the e-tag that is not the generation
source.
(p) "Electricity
transaction" means the purchase, sale, import, export or exchange of electric
power.
(q) "Energy imbalance
market" or "EIM" means the western energy imbalance market operated by the
California independent system operator.
(r) "Exported electricity" means electricity
generated inside Washington state and delivered to serve load located outside
Washington state. This includes electricity delivered from a first point of
receipt inside Washington state, to the first point of delivery outside
Washington state, with a final point of delivery outside Washington state.
Exported electricity delivered across balancing authority areas is documented
on e-tags with the first point of receipt located inside Washington state and
the final point of delivery located outside Washington state. Exported
electricity does not include electricity generated inside Washington state then
transmitted outside of Washington state, but with a final point of delivery
inside Washington state. Exported electricity does not include electricity
generated inside Washington state that is allocated to serve Washington state
retail customers of a multijurisdictional retail provider, consistent with a
cost allocation methodology approved by the Washington state utilities and
transportation commission and the utility regulatory commission of at least one
additional state in which the multijuris-dictional retail provider provides
retail electric service.
(s) "Final
point of delivery" means the sink specified on the e-tag, where defined points
have been established through the affiliated registry. When e-tags are not used
to document electricity deliveries, as may be the case within a balancing
authority, the final point of delivery is the location of the load. Exported
electricity is disaggregated by the final point of delivery on the
e-tag.
(t) "First point of delivery
in Washington" means the first defined point on the transmission system located
inside Washington state at which imported electricity may be measured,
consistent with defined points that have been established through the
affiliated registry.
(u) "First
point of receipt" means the generation source specified on the e-tag, where
defined points have been established through the affiliated registry. When
e-tags are not used to document electricity deliveries, as may be the case
within a balancing authority, the first point of receipt is the location of the
individual generating facility or unit, or group of generating facilities or
units.
(v) "Grid" or "electric
power grid" means a system of synchronized power providers and consumers
connected by transmission and distribution lines and operated by one or more
control centers.
(w) "Last point of
delivery in Washington" means the last defined point on the transmission system
located inside Washington state at which exported electricity may be measured,
consistent with defined points that have been established through the North
American Energy Standards Board Electric Industry Registry.
(x) "Marketer" means a purchasing-selling
entity that delivers electricity and is not a retail provider.
(y) "Point of receipt" or "POR" means the
point on an electricity transmission or distribution system where an
electricity receiver receives electricity from a deliverer. This point can be
an interconnection with another system or a substation where the transmission
provider's transmission and distribution systems are connected to another
system.
(z) "Power" means
electricity, except where the context makes clear that another meaning is
intended.
(aa) "Power contract" or
"written power contract," as used for the purposes of documenting specified
versus unspecified sources of imported and exported electricity, means a
written document, including associated verbal or electronic records if included
as part of the written power contract, arranging for the procurement of
electricity. Power contracts may be, but are not limited to, power purchase
agreements, enabling agreements, electricity transactions, and tariff
provisions, without regard to duration, or written agreements to import or
export on behalf of another entity, as long as that other entity also reports
to ecology the same imported or exported electricity. A power contract for a
specified source is a contract that is contingent upon delivery of power from a
particular facility, unit, or asset-controlling supplier's system that is
designated at the time the transaction is executed.
(bb) "Purchasing-selling entity" or "PSE"
means the entity that is identified on an e-tag for each physical path
segment.
(cc) "Retail end use
customer" or "retail end user" means a residential, commercial, agricultural,
or industrial electric customer who buys electricity to be consumed as a final
product and not for resale.
(dd)
"Retail sales" means electricity sold to retail end users.
(ee) "Sink" or "sink to load" or "load sink"
means the sink identified on the physical path of e-tags, where defined points
have been established through the affiliated registry. Exported electricity is
disaggregated by the sink on the e-tag, also referred to as the final point of
delivery on the e-tag.
(ff) "Source
of generation" or "generation source" means the generation source identified on
the physical path of e-tags, where defined points have been established through
the affiliated registry.
Imported electricity and wheels are disaggregated by the source
on the e-tag, also referred to as the first point of receipt.
(gg) "Tolling agreement" means an agreement
whereby a party rents a power plant from the owner. The rent is generally in
the form of a fixed monthly payment plus a charge for every megawatt generated,
generally referred to as a variable payment.
(3)
Data requirements and calculation
methods. The electric power entity who is required to report under WAC
173-441-030(3)
of this chapter must comply with the following requirements.
(a) General requirements and content for GHG
emissions data reports for electricity importers and exporters.
(i) Greenhouse gas emissions. The electric
power entity must report GHG emissions separately for each category of
delivered electricity required, in metric tons of CO2
equivalent (MT of CO2e), with bio-genic
CO2 reported separately, according to the calculation
methods in this section.
(ii)
Delivered electricity. The electric power entity must report imported and
exported electricity in MWh disaggregated by first point of receipt (POR) or
final point of delivery, as applicable, and must also separately report
imported and exported electricity from unspecified sources and the energy
imbalance market, and from each specified source. First points of receipt and
final points of delivery (POD) must be reported using the standardized code
used in e-tags, as well as the full name of the POR/POD.
(iii) Imported electricity from unspecified
sources. When reporting imported electricity delivered from unspecified
sources, the electric power entity must report for each first point of receipt
the following information:
(A) Whether the
first point of receipt is located in a linked jurisdiction published on the
ecology website;
(B) The amount of
electricity from unspecified sources as measured at the first point of delivery
in Washington state;
(C) The amount
of electricity imports of unspecified electricity that are netted by exports of
unspecified electricity to any jurisdiction not covered by a linked program by
the same entity within the same hour.
(D) The net amount of imported unspecified
electricity after taking into account the requirements in (a)(iii)(C) of this
subsection.
(E) GHG emissions,
including those associated with transmission losses, as required in this
section.
(F) When the unspecified
power was obtained from the energy imbalance market.
(iv) Delivered electricity from specified
facilities or units. The electric power entity must report all direct delivery
of electricity as from a specified source for facilities or units in which they
are a generation providing entity (GPE) or have a written power contract to
procure electricity. An electric power entity must report imported electricity
as from a specified source when the electricity power entity is a GPE of that
facility. When reporting imported electricity from specified facilities or
units, the electric power entity must disaggregate electricity deliveries and
associated GHG emissions by facility or unit and by first point of receipt, as
applicable. The reporting entity must also report total GHG emissions and MWh
from specified sources and the sum of emissions from specified sources
explicitly listed as not covered in chapter 70A.65 RCW, as described in chapter
173-446 WAC. Seller Warranty: The sale or resale of specified source
electricity is permitted among entities on the e-tag market path insofar as
each sale or resale is for specified source electricity in which sellers have
purchased and sold specified source electricity, such that each seller warrants
the sale of specified source electricity from the source through the market
path. Claims of specified sources of imported electricity, must include the
following information:
(A) Measured at busbar.
The amount of imported electricity from specified facilities or units as
measured at the busbar; and
(B) Not
measured at busbar. If the amount of imported electricity deliveries from
specified facilities or units as measured at the busbar is not provided, report
the amount of imported electricity as measured at the first point of delivery
in Washington state, including estimated transmission losses as required in
this section and the reason why measurement at the busbar is not
known.
(v) Imported
electricity from the energy imbalance market. The reporting entity must
separately report power obtained from the energy imbalance market.
(vi) Imported electricity supplied by
asset-controlling suppliers. The reporting entity must separately report
imported electricity supplied by asset-controlling suppliers recognized by
ecology. The reporting entity must:
(A) Report
the asset-controlling supplier standardized purchasing-selling entity (PSE)
acronym or code, full name, and the ecology identification number;
(B) Report asset-controlling supplier power
that was not acquired as specified power, as unspecified power;
(C) Report delivered electricity from
asset-controlling suppliers as measured at the first point of delivery in
Washington state; and
(D) Report
GHG emissions calculated pursuant to this section, including transmission
losses.
(E) To claim power from an
asset-controlling supplier, the asset-controlling supplier must be identified
in one of the following means:
(I) On the
physical path of the e-tag as the PSE at the first point of receipt, or in the
case of asset-controlling suppliers that are exclusive marketers, as the PSE
immediately following the associated generation owner; or
(II) If there is no e-tag associated with the
imported electricity, on a long-term contract that identifies the ACS as the
relevant provider of that electricity.
(vii) Exported electricity. The electric
power entity must report exported electricity in MWh and associated GHG
emissions in MT of CO2e for unspecified sources
disaggregated by each final point of delivery outside Washington state, and for
each specified source disaggregated by each final point of delivery outside
Washington state, as well as the following information:
(A) Exported electricity as measured at the
last point of delivery located in Washington state, if known. If unknown,
report as measured at the final point of delivery outside Washington
state.
(B) Do not report estimated
transmission losses.
(C) Report
whether the final point of delivery is located in a linked jurisdiction
published on the ecology website.
(D) Report GHG emissions calculated pursuant
to this section.
(viii)
Exchange agreements. The electric power entity must report delivered
electricity under power exchange agreements consistent with imported and
exported electricity requirements of this section. Electricity delivered into
Washington state under exchange agreements must be reported as imported
electricity and electricity delivered out of Washington state under exchange
agreements must be reported as exported electricity.
(ix) Verification documentation. The electric
power entity must retain for purposes of verification documentation of e-tags,
written power contracts, settlements data, and all other information required
to confirm reported electricity procurements and deliveries pursuant to the
recordkeeping requirements of WAC
173-441-050.
(x) Electricity generating units and
cogeneration units in Washington state. Electric power entities that also
operate electricity generating units or cogeneration units located inside
Washington state that meet the applicability requirements of WAC
173-441-030(1)
must report GHG emissions to ecology under
WAC
173-441-120.
(xi) Electricity generating units and
cogeneration units outside Washington state. Operators and owners of
electricity generating units and cogeneration units located outside Washington
state who elect to report to ecology under WAC
173-441-030(5)
must fully comply with the reporting and verification requirements of this
chapter.
(b) Calculating
GHG emissions.
(i) Calculating GHG emissions
from unspecified sources. For electricity from unspecified sources, the
electric power entity must calculate the annual CO2
equivalent mass emissions using the method established in WAC
173-444-040(4)
and based on the amount of net imported
electricity reported consistent with (a)(iii)(D) of this subsection.
(ii) Calculating GHG emissions from specified
facilities or units. For electricity from specified facilities or units, the
electric power entity must calculate emissions using the following equation:
CO2e = MWh ×TL
×EFsp (Eq. 124-1)
Where:
CO2e = Annual CO2
equivalent mass emissions from the specified electricity deliveries from each
facility or unit claimed (MT of CO2e).
MWh = Megawatt-hours of specified electricity deliveries from
each facility or unit claimed.
EFsp = Facility-specific or unit-specific emission factor
published on the ecology website and calculated using total emissions and
transactions data as described below. The emission factor is based on data from
the year prior to the reporting year.
TL = Transmission loss correction factor.
TL = 1.02 to account for transmission losses associated with
generation outside of a Washington state balancing authority.
TL = 1.0 if the reporting entity provides documentation that
demonstrates to the satisfaction of a verifier and ecology that transmission
losses have been accounted for, or are compensated by using electricity sourced
from within Washington state.
(A)
Ecology shall calculate facility-specific or unit-specific emission factors and
publish them on the ecology website using the following equation:
EFsp = Esp/EG (Eq. 124-2)
Where:
Esp = CO2e emissions for a specified
facility or unit for the report year (MT of
CO2e).
EG = Net generation from a specified facility or unit for the
report year shall be based on data reported to the Energy Information
Administration (EIA).
(B) To
register a specified unit(s) source of power, the reporting entity must provide
to ecology unit level GHG emissions consistent with the data source
requirements of this section and net generation data as reported to the EIA,
along with contracts for delivery of power from the specified unit(s) to the
reporting entity, and proof of direct delivery of the power by the reporting
entity as an import to Washington state.
(I)
For specified facilities or units whose operators are subject to this chapter
or whose owners or operators voluntarily report under this chapter, Esp shall
be equal to the sum of CO2e emissions reported pursuant
to this section.
(II) For specified
facilities or units whose operators are not subject to reporting under this
chapter or whose owners or operators do not voluntarily report under this
chapter, but are subject to the U.S. EPA GHG Mandatory Reporting Regulation,
Esp shall be based on GHG emissions reported to U.S. EPA pursuant to 40 C.F.R.
Part 98 . For GHG emissions reported to U.S. EPA pursuant to 40 C.F.R. Part 98,
if it is not possible to isolate the emissions that are directly related to
electricity production, ecology may calculate Esp based on EIA data. Emissions
from combustion of biomass-derived fuels will be based on EIA data until such
time the emissions are reported to U.S. EPA.
(III) For specified facilities or units whose
operators are not subject to reporting under this chapter or whose owners or
operators do not voluntarily report under this chapter, nor are subject to the
U.S. EPA GHG Mandatory Reporting Regulation, Esp is calculated using heat of
combustion data reported to the Energy Information Administration (EIA) as
shown below.
Esp = 0.001 ×[SIGMA] (Q x EF) (Eq. 124-3)
Where:
0.001 = Conversion factor kg to MT
Q = Heat of combustion for each specified fuel type from the
specified facility or unit for the report year (MMBtu). For cogeneration, Q is
the quantity of fuel allocated to electricity generation consistent with EIA
reporting. For geothermal electricity, Q is the steam data reported to EIA
(MMBtu).
EF = CO2e emission factor for the
specified fuel type as required by this chapter (kg
CO2e/MMBtu). For geothermal electricity, EF is the
estimated CO2 emission factor published by
EIA.
(IV) Facilities or units
will be assigned an emission factor by the ecology based on the type of fuel
combusted or the technology used when a U.S. EPA GHG Report or EIA fuel
consumption report is not available, including new facilities and facilities
located outside the U.S.
(V) Meter
data requirement. For verification purposes, electric power entities shall
retain meter generation data to document that the power claimed by the
reporting entity was generated by the facility or unit at the time the power
was directly delivered.
(VI) A
lesser of analysis is applicable to imports from specified sources for which
ecology has calculated an emission factor of zero, and for imports from
Washington renewable portfolio standard (RPS) eligible resources, excluding the
following: Dynamically tagged power deliveries; nuclear power; asset
controlling supplier power; and imports from hydroelectric facilities for which
an entity's share of me-tered output on an hourly basis is not established by
power contract. A lesser of analysis is required pursuant to the following
equation:
Sum of Lesser of MWh = [SIGMA]Msp min
(MGsp*Ssp, TGsp) (Eq. 124-4)
Where:
[SIGMA]HMsp = Sum of the Hourly Minimum
of MGsp and TGsp (MWh).
MGsp = Metered facility or unit net
generation (MWh).
Ssp = Entity's share of metered output,
if applicable.
TGsp = Tagged or transmitted energy at
the transmission or subtransmission level imported to Washington (MWh).
(iii)
Calculating GHG emissions of imported electricity supplied by asset-controlling
suppliers. Based on annual reports submitted to ecology pursuant to WAC
173-441-070(3),
ecology will calculate and publish on the ecology website the system emission
factor for all asset-controlling suppliers recognized by the ecology. The
reporting entity must calculate emissions for electricity supplied using the
following equation:
CO2e = MWh ×TL
×EFacs (Eq. 124-5)
Where:
CO2 = Annual CO2
equivalent mass emissions from the specified electricity deliveries from
ecology-recognized asset-controlling suppliers (MT of
CO2e).
MWh = Megawatt-hours of specified electricity
deliveries.
EFACS = Asset-Controlling Supplier system emission factor
published on the ecology website (MT CO2e/MWh). Ecology
will assign the system emission factors for all asset-controlling suppliers
based on a previously verified GHG report submitted to ecology pursuant to WAC
173-441-070(3).
The supplier-specific system emission factor is calculated annually by ecology.
The calculation is derived from data contained in annual reports submitted that
have received a positive or qualified positive verification statement. The
emission factor is based on data from two years prior to the reporting
year.
TL = Transmission loss correction factor.
TL = 1.02 when deliveries are not reported as measured at a
first point of receipt located within the balancing authority area of the
asset-controlling supplier.
TL = 1.0 when deliveries are reported as measured at a first
point of receipt located within the balancing authority area of the
asset-controlling supplier.
Ecology must calculate the system emission factor for
asset-controlling suppliers using the following equations:
EFACS = Sum of System Emissions MT of
CO2e/Sum of System MWh (Eq. 124-6)
Sum of System Emissions, MT of CO2e =
[SIGMA]Easp + [SIGMA](PEsp *
EFsp) + [SIGMA](PEunsp *
EFunsp) - [SIGMA](SEsp *
EFsp) (Eq. 124-7)
Sum of System MWh = [SIGMA]EGasp +
[SIGMA]PEsp + [SIGMA]PEunsp -
[SIGMA]SEsp (Eq. 124-8)
Where:
[SIGMA]Easp = Emissions
from owned facilities. Sum of CO2e emissions from each
specified facility/unit in the asset-controlling supplier's fleet (MT of
CO2e).
[SIGMA]EGasp = Net generation from
owned facilities. Sum of net generation for each specified facility/unit in the
asset-controlling supplier's fleet for the data year as reported to ecology
under this chapter (MWh).
PEsp = Electricity purchased from
specified sources. Amount of electricity purchased wholesale and taken from
specified sources by the asset-controlling supplier for the data year as
reported to ecology under this chapter (MWh).
PEunsp = Electricity purchased from
unspecified sources. Amount of electricity purchased wholesale from unspecified
sources by the asset-controlling supplier for the data year as reported to
ecology under this chapter (MWh).
SEsp = Electricity sold from specified
sources. Amount of wholesale electricity sold from specified sources by the
asset-controlling supplier for the data year as reported to ecology under this
chapter (MWh).
EFsp = CO2e
emission factor as defined for each specified facility or unit calculated
consistent with (b)(ii) of this subsection (MT
CO2e/MWh).
EFunsp = Default emission factor for
unspecified sources calculated consistent with (b)(i) of this subsection (MT
CO2e/MWh).
(iv) Calculating GHG emissions of imported
electricity for multi-jurisdictional retail providers. Multijurisdictional
retail providers must include emissions and megawatt-hours in the terms below
from facilities or units that contribute to a common system power pool.
Mul-tijurisdictional retail providers do not include emissions or
megawatt-hours in the terms below from facilities or units allocated to serve
retail loads in designated states pursuant to a cost allocation methodology
approved by the Washington state utilities and transportation commission and
the utility regulatory commission of at least one additional state in which the
multijurisdictional retail provider provides retail electric service. For
multijurisdictional consumer-owned utilities, the cost allocation methodology
must be approved by its governing board. Multijurisdictional retail providers
must calculate emissions that have a compliance obligation using the following
equation:
CO2e = (MWhR x TLR - MWhWSP-WA - EGWA) x
EFMJRP-notWA + MWhSP-notWA x TLWSP x EFunsp - CO2e
linked (Eq. 124-9)
Where:
CO2e = Annual
CO2e mass emissions of imported electricity (MT of
CO2e).
MWhR = Total electricity procured by multijurisdictional retail
provider to serve its retail customers in Washington, reported as retail sales
for Washington state service territory, MWh.
MWhWSP- WA = Wholesale electricity procured in Washingtonstate
by multijurisdictional retail provider to serve its retail customers in
Washington state, as determined by the first point of receipt on a e-tag and
pursuant to a cost allocation methodology approved by the Washington state
utilities and transportation commission (UTC) and the utility regulatory
commission of at least one additional state in which the multijurisdictional
retail provider provides retail electric service, MWh. For multijurisdictional
consumer-owned utilities, the cost allocation methodology must be approved by
its governing board.
MWhWSP-not WA = Wholesale electricity imported into Washington
state by multijurisdictional retail provider with a final point of delivery in
Washington state and not used to serve its Washington state retail customers,
MWh.
EFMJRP-not WA = Multijurisdictional retail provider system
emission factor for out-of-state generation calculated by ecology and
consistent with a cost allocation methodology approved by the Washington state
utilities and transportation commission and the utility regulatory commission
of at least one additional state in which the multijurisdictional retail
provider provides retail electric service. For multijurisdictional
consumer-owned utilities, the cost allocation methodology must be approved by
its governing board.
EFunsp = Default emission factor for
unspecified sources calculated consistent with this section (MT
CO2e/MWh).
EGWA = Net generation measured at the busbar of facilities and
units located in Washington state that are allocated to serve its retail
customers in Washington state pursuant to a cost allocation methodology
approved by the Washington state utilities and transportation commission and
the utility regulatory commission of at least one additional state in which the
multijurisdictional retail provider provides retail electric service, MWh. For
multijurisdictional consumer-owned utilities, the cost allocation methodology
must be approved by its governing board.
TL = Transmission loss correction factor.
TL WSP = 1.02 for transmission losses applied to wholesale
power.
TL R = Estimate of transmission losses from busbar to end user
reported by multijurisdictional retail provider.
CO2e = Annual
CO2e mass emissions recognized by linked ecology
pursuant to linkage under chapter 70A. 65 RCW, as described in chapter 173-446
WAC (MT of CO2e).
(c) Additional requirements for retail
providers, excluding mul-tijurisdictional retail providers. Retail providers
must include the following information in the GHG emissions data report for
each report year, in addition to the information identified in (a)(i), (ii),
and (vii) of this subsection.
(i) Retail
providers must report Washington state retail sales. A retail provider who is
required only to report retail sales may choose not to apply the verification
requirements specified in WAC
173-441-085,
if the retail provider deems the emissions data report
nonconfidential.
(ii) Retail
providers may elect to report the subset of retail sales attributed to the
electrification of shipping ports, truck stops, and motor vehicles if metering
is available to separately track these sales from other retail
sales.
(d) Retail
providers that report as electricity importers or exporters also must
separately report electricity imported from specified and unspecified sources
by other electric power entities to serve their load, designating the
electricity importer. In addition, all imported electricity transactions
documented by e-tags where the retail provider is the PSE at the sink must be
reported.
(e) Additional
requirements for multijurisdictional retail providers. Multijurisdictional
retail providers that provide electricity into Washington state at the
distribution level must include the following information in the GHG emissions
data report for each report year, in addition to the information identified
elsewhere in this section.
(i) A report of the
electricity transactions and GHG emissions associated with the common power
system or contiguous service territory that includes consumers in Washington
state. This includes the requirements in this section as applicable for each
generating facility or unit in the multijurisdictional retail provider's
fleet;
(ii) The multijurisdictional
retail provider must include in its emissions data report wholesale power
purchased and taken (MWh) from specified and unspecified sources and wholesale
power sold from specified sources according to the specifications in this
section, and as required for ecology to calculate a supplier-specific emission
factor;
(iii) Total retail sales
(MWh) by the multijurisdictional retail provider in the contiguous service
territory or power system that includes consumers in Washington
state;
(iv) Retail sales (MWh) to
Washington state customers served in Washington state's portion of the service
territory;
(v) Retail sales derived
from the energy imbalance market;
(vi) GHG emissions associated with the
imported electricity, including both Washington state retail sales and
wholesale power imported into Washington state from the retail provider's
system, according to the specifications in this section;
(vii) Multijurisdictional retail providers
that serve Washington state load must claim as specified power all power
purchased or taken from facilities or units in which they have operational
control or an ownership share or written power contract;
(viii) Multijurisdictional retail providers
that serve Washington state load may elect to exclude information listed in
this section when registering claims to specified power from facilities located
outside Washington state and participating in the Federal Energy Regulatory
Commission's PURPA Qualifying Facility program.
(f) Additional requirements for
asset-controlling suppliers. Owners or operators of electricity generating
facilities or exclusive marketers for certain generating facilities may apply
for an asset-controlling supplier designation from ecology. Approved
asset-controlling suppliers may request that ecology calculate or adopt a
supplier-specific emission factor pursuant to this section. To apply for
asset-controlling supplier designation, the applicant must:
(i) Meet the requirements in this chapter,
including reporting pursuant as applicable for each generating facility or unit
in the supplier's fleet;
(ii)
Include in its emissions data report wholesale power purchased and taken (MWh)
from specified and unspecified sources and wholesale power sold from specified
sources according to the specifications in this section, and as required for
ecology to calculate a supplier-specific emission factor;
(iii) Retain for verification purposes
documentation that the power sold by the supplier originated from the
supplier's fleet of facilities and either that the fleet is under the
supplier's operational control or that the supplier serves as the fleet's
exclusive marketer;
(iv) Provide
the supplier-specific ecology identification number to electric power entities
who purchase electricity from the supplier's system.
(v) To apply for and maintain
asset-controlling supplier status, the entity shall submit as part of its
emissions data report the following information, annually:
(A) General business information, including
entity name and contact information;
(B) List of officer names and
titles;
(C) Data requirements as
prescribed by ecology;
(D) A list
and description of electricity generating facilities for which the reporting
entity is a first jurisdiction deliverer; and
(E) An attestation, in writing and signed by
an authorized officer of the applicant, as follows:
(I) "I certify under penalty of perjury under
the laws of the State of Washington that I am duly authorized by (name of
entity) to sign this attestation on behalf of (name of entity), that (name of
entity) meets the definition of an asset-controlling supplier as specified in
this section and that the information submitted herein is true, accurate, and
complete."
(II) Asset-controlling
suppliers must annually adhere to all reporting and verification requirements
of this chapter, or be removed from asset-controlling supplier designation.
Asset-controlling suppliers will also lose their designation if they receive an
adverse verification statement, but may reapply in the following year for
redesig-nation.
(g) Requirements for claims of specified
sources of electricity. Each reporting entity claiming specified facilities or
units for imported or exported electricity must register its anticipated
specified sources with ecology as part of their greenhouse gas report to obtain
associated emission factors calculated by ecology for use in the emissions data
report required to be submitted by the report submission due date in WAC
173-441-050(2)(a).
If an operator fails to register a specified source by the registration due
date in WAC
173-441-060(4),
the operator must use the emission factor provided by ecology for a specified
facility or unit in the emissions data report required to be submitted by the
report submission due date in WAC
173-441-050(2)(a).
Each reporting entity claiming specified facilities or units for imported or
exported electricity must also meet requirements in the emissions data report.
(i) Registration information for specified
sources. The following information is required:
(A) The facility names and, for specification
to the unit level, the facility and unit names.
(B) For sources with a previously assigned
ecology identification number, the ecology facility or unit identification
number or supplier number published on ecology's website. For newly specified
sources, ecology will assign a unique identification number.
(C) If applicable, the facility and unit
identification numbers as used for reporting to the U.S. EPA Acid Rain Program,
U.S. EPA pursuant to 40 C.F.R. Part 98 , U.S. Energy Information
Administration, Federal Energy Regulatory Commission's PURPA Qualifying
Facility program, as applicable.
(D) The physical address of each facility,
including jurisdiction.
(E) Provide
names of facility owner and operator.
(F) The percent ownership share and whether
the facility or unit is under the electricity importer's operational
control.
(G) Total facility or unit
gross and net nameplate capacity when the electricity importer is a
GPE.
(H) Total facility or unit
gross and net generation when the electricity importer is a GPE.
(I) Start date of commercial operation and,
when applicable, date of repowering.
(J) GPEs claiming additional capacity at an
existing facility must include the implementation date, the expected increase
in net generation (MWh), and a description of the actions taken to increase
capacity.
(K) Designate whether the
facility or unit is a newly specified source, a continuing specified source, or
was a specified source in the previous report year that will not be specified
in the current report year.
(L)
Provide the primary technology or fuel type as listed below:
(I) Variable renewable resources by type,
defined for purposes of this chapter as pure solar, pure wind, and run-of-river
hydroelectricity;
(II) Hybrid
facilities such as solar thermal;
(III) Hydroelectric facilities [LESS THAN
EQUAL TO] 30 MW, not run-of-river;
(IV) Hydroelectric facilities [GREATER THAN
EQUAL TO] 30 MW;
(V) Geothermal
binary cycle plant or closed loop system;
(VI) Geothermal steam plant or open loop
system;
(VII) Units combusting
biomass-derived fuel, by primary fuel type;
(VIII) Nuclear facilities;
(IX) Cogeneration by primary fuel
type;
(X) Fossil sources by primary
fuel type;
(XI) Co-fired
fuels;
(XII) Municipal solid waste
combustion;
(XIII) Other.
(ii) Additional
information for specified sources. For each claim to a specified source of
electricity, the electricity importer must indicate whether one or more of the
following descriptions applies:
(A) Deliveries
from new facilities. Specified source of electricity is first registered
pursuant to this section and delivered by an electricity importer within 12
months of the start date of commercial operation and the electricity importer
making a claim in the current data year is either a GPE or purchaser of
electricity under a written power contract;
(B) Deliveries from existing facilities with
additional capacity. Specified source of electricity is first registered
pursuant to this section and delivered by a GPE within 12 months of the start
date of an increase in the facility's generating capacity due to increased
efficiencies or other capacity increasing actions.
(4)
Recordkeeping. GHG inventory program for electric power entities
that import or export electricity. In lieu of a GHG monitoring plan, electric
power entities that import or export electricity must prepare GHG inventory
program documentation that is maintained and available for verifier review and
ecology audit pursuant to the re-cordkeeping requirements of this section. The
following information is required:
(a)
Information to allow the verification team to develop a general understanding
of entity boundaries, operations, and electricity transactions;
(b) Reference to management policies or
practices applicable to reporting pursuant to this section;
(c) List of key personnel involved in
compiling data and preparing the emissions data report;
(d) Training practices for personnel involved
in reporting delivered electricity and responsible for data report
certification, including documented training procedures;
(e) Query of e-tag source data to determine
the quantity of electricity (MWh) imported, exported, and wheeled for
transactions in which they are the purchasing-selling entity on the last
physical path segment that crosses the border of Washington state, access to
review the raw e-tag data, a tabulated summary, and query
description;
(f) Reference to other
independent or internal data management systems and records, including written
power contracts and associated verbal or electronic records, full or partial
ownership, invoices, and settlements data used to document whether reported
transactions are specified or unspecified and whether the requirements for
adjustments to covered emissions of chapter 70A.65 RCW, as described in chapter
173-446 WAC are met;
(g)
Description of steps taken and calculations made to aggregate data into
reporting categories required pursuant to this section;
(h) Records of preventive and corrective
actions taken to address verifier and ecology findings of past nonconformances
and material misstatements;
(i) Log
of emissions data report modifications made after initial certification;
and
(j) A written description of an
internal audit program that includes emissions data report review and documents
ongoing efforts to improve the GHG inventory
program.