20231018AVU to Staff 4 Attachment B.pdf

105 Qualifying Resources PAGE 0

Western Resource
Adequacy Program

100 – Forward Showing
105 Qualifying Resources
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Revision History
Manual Number Version Description Revised By Date
105 1.0 Qualifying Resources Rebecca
Sexton 6/23/2023
105 1.1 Qualifying Resources Rebecca
Sexton 8/11/2023
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Table of Contents
Revision History ...................................................................................................... 1
105 Qualifying Resources ........................................................................................ 3
1 Introduction .................................................................................................. 3
1.1 Intended Audience ................................................................................... 3
1.2 What You Will Find in This Manual ............................................................ 3
1.3 Purpose .................................................................................................. 3
1.4 Definitions ............................................................................................... 3
2 Background ................................................................................................... 4
3 Resource Registration .................................................................................... 5
3.1 Resource Eligibility .................................................................................. 5
3.2 Late Registration of Resources .................................................................. 5
3.3 Qualifying Resource Aggregation (Resources <1 MW) ............................... 10
3.4 Generator Testing ................................................................................. 11
4 Qualifying Capacity Contribution of Resources ................................................ 17
4.1 Background ........................................................................................... 17
4.2 Thermal or Long Duration Storage Resources ........................................... 17
4.3 Variable Energy Resources ..................................................................... 22
4.4 Energy Storage ...................................................................................... 29
4.5 Hybrid Facilities ..................................................................................... 30
4.6 Demand Response ................................................................................. 30
4.7 Hydro Resources ................................................................................... 31
4.8 Other Resources .................................................................................... 33
Appendix A – Qualified Capacity Contribution for Storage Hydro Resources ............ 35
5.1 Time Period Approach for Summer and Winter Season Requirements ......... 35
5.2 Treatment of Planned Outages ............................................................... 37
5.3 Treatment of Non-Power Constraints ....................................................... 39
5.4 Treatment of Cascaded and Coordinated Hydro Systems ........................... 39
5.5 Form To Complete Storage Hydro Resource QCC ...................................... 39

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105 Qualifying Resources
1 Introduction
The Qualifying Resources Business Practice Manual (BPM) consists of two sections. The
Resource Registration section outlines the processes for Participants to register their
Qualifying Resources with the Program Operator (PO) to be included in the Advance
Assessment to receive a Qualifying Capacity Contribution (QCC). The Qualifying
Capacity Contribution of Resources section outlines the processes that the PO will
undertake to calculate QCC values for all registered Qualifying Resources.
1.1 Intended Audience
This BPM is intended for Western Power Pool (WPP) Western Resource Adequacy
Program (WRAP) Participants and other interested individuals or entities. This BPM is
particularly useful for those individuals that are responsible for their Participant
organization’s Forward Showing (FS) Submittal and need to ensure that their
organization’s Qualifying Resources are properly registered, will be included in the
Advance Assessment, and will receive QCC values.
1.2 What You Will Find in This Manual
This BPM includes two separate Business Practices: 1) Resource Registration and 2)
Qualifying Capacity Contribution of Resources.
1.3 Purpose
To provide an overview of Resource Registration and Qualification processes and the
process for determining the QCC for Qualified Resources.
1.4 Definitions
All capitalized terms that are not otherwise defined in this BPM have the meaning set
forth in the Tariff. Any capitalized terms not found in the Tariff that are specific to this
BPM are defined here.
Cascaded Dual Plant: Two hydro generation resources that are on the same river
systems and operated in a coordinated manner.
Capability Test: The demonstration of capability of certain Qualifying Resources by
generating at their rated capability under specified test conditions and test duration.
Hybrid Facility: A resource that is composed of two or more resources of different
fuel or technology types where one of those resources is an Energy Storage Resource
with the same interconnection point.
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Long Duration Storage: A resource designed to capture energy produced at one time
for use at a later time, and capable of sustained delivery for over 8 hours (such as
pumped Storage Hydro facilities or thermal energy storage devices)
Net Generating Capability: The gross maximum output of a Qualifying Resource
reduced by any power used for auxiliary power requirements demonstrated through a
Capability Test. May be used interchangeably with Installed Capacity when referencing
thermal resources.
Operational Test: The annual demonstration of the functional ability of a Qualifying
Resource.
Data Instruction Manual: The set of instructions provided by WPP to facilitate
Participants filling out the Advance Assessment data request.
ASHRAE Rated Ambient Temperature: The ambient temperature employed for
Capability Testing of a resource for the Summer Season, as determined for the resource
location on a dry-bulb basis in accordance with the American Society of Heating,
Refrigerating and Air-Conditioning Engineers (ASHRAE) Fundamentals Handbook,1
Climatic Design Information, Cooling and Dehumidification Design Conditions Appendix
using the – “Cooling DB/MCWB 0.4%” values. If the resource is located within 30 miles
of the nearest weather station reported in the Handbook, then the temperatures
employed for the Rated Ambient Temperature will be those reported for the nearest
station. For all other resource locations, the Rated Ambient Temperatures shall be
determined by interpolating between those reported for appropriate weather stations
using the resource location’s latitude and longitude.
Hydro QCC Workbook: The workbook that determines the QCC of a single Storage
Hydro generation resource.
2 Background
Participant owned and contracted Qualifying Resources capable of providing capacity
may be used to meet a Participant’s FS Capacity Requirement. In order to receive a
QCC for these Qualifying Resources, a Participant must provide the necessary
information and data to the PO. The PO will develop and maintain a registration and
certification process for all Qualifying Resources identified for the FS Program as
outlined in this BPM. This BPM does not cover timelines associated with Participants and

1 ASHRAE Fundamentals Handbook
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the PO completing the registration and QCC assessment process. Timelines for
registration can be found in BPM 101 – Advance Assessment Timeline.

3 Resource Registration
3.1 Resource Eligibility
A Participant will register all owned resources in its portfolio and all resources acquired
in resource specific contracts in order for those resources to receive QCC values,
subject to the exceptions described in this BPM.
Resource registrations, including the appropriate modeling data required by the PO,
shall be submitted in accordance with deadlines stated in BPM 101 Advance
Assessment, relating to the timeline for the Advance Assessment.
Participants shall employ the Advance Assessment data request workbook, and the
guidance and instructions in the Data Instruction Manual for providing Resource
Registration information. The then-effective versions of the Advance Assessment data
request workbook and the Data Instruction Manual shall be made available at an
appropriate location on the WPP website. The QCC calculations for all Qualified
Resources will be updated during each Advance Assessment to be used for the
applicable Binding Season.
Resources owned and operated by entities that are not Participants and contracted to
Participants with resource specific contracts (i.e., not system sales or block contracts)
must be registered with the PO and provide the necessary data in order for Participants
to claim the full QCC from these resources toward their FS Capacity Requirements.
Qualified Resources must be 1 MW minimum to qualify for registration (see Section
3.3). The registration process for all Qualifying Resources, other than Storage Hydro
Qualifying Resources, will require, but will not be limited to, provision of the information
set forth in Table 1 and Table 2 to the PO, by means of the Advance Assessment data
request workbook. Registration of Storage Hydro Qualifying Resources will require, but
will not be limited to, the provisions of items set forth in Table 3 to the PO, by means of
the Advance Assessment data request workbook.
3.2 Late Registration of Resources
Resources that are unable to register by the deadline of the Advance Assessment data
request may still be able to register through the following processes. Such resources
may include those owned by Participants or those contracted to Participants with
resource specific contracts.
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A Participant may register a resource after the Advance Assessment deadline and prior
to the FS Submittal Deadline (the process and timeline for submitting the FS Submittal
can be found in BPM 108 Forward Showing Submittal) provided the Participant provides
the necessary information in Table 1 and Table 2 of this BPM (or Table 3 for Storage
Hydro resources). The QCC that will be allowed for late registered resources will be
either the class average of similar resources or will be a discounted QCC based on the
circumstances of the data provided as further described in Generator Testing (Section
3.4) and Qualifying Capacity Contribution of Resources (Section 4).
Given that the program has very little information about late registered Qualified
Resources, such resources may constitute no more than 10% of the total FS Capacity
Requirement for an individual Participant, unless that Participant can demonstrate an
increase in the load participating in the WRAP after the Advance Assessment data
collection deadline. In the case of increased load, the Participant may provide late
registered resources to meet the FS Capacity Requirement for the additional load, as
well as f the load anticipated to participate at the time of the Advance Assessment data
collection deadline.
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Table 1. Information Required for Resource Registration
Description / Instructions
Facility Name Plant name of the resources. If possible, utilize the Energy
Information Administration (EIA)-8602 plant name given for U.S.
resources.
Unit ID The unique generator identification commonly used by plant
management. If possible, utilize the EIA-860 Generator ID given for
U.S. resources.
Prime Mover Utilize the predetermined dropdown list of EIA-860 Prime Mover
identifiers. For combined cycle resources, a prime mover code must
be entered for each generator.
Fuel Type Utilize the predetermined dropdown list in the workbook of fuel types
used as the primary energy source to power the generator.
Host Balancing
Authority
Provide the Balancing Authority Area (BAA) in which the resource is
located.
Ownership or
Contracted
Percentage for
Participant
Enter the percentage of resource capability owned or contracted by
the Participant. This should also include the percentage of any power
purchase agreement (PPA) where the Participant has fully contracted
for the capacity from a facility but would not include a PPA with
another Participant. For example, if the Participant has a PPA with a
wind developer, solar developer, or city that has local generation for
an extended period of time (i.e., 15 years or life of the facility) then
the percentage of the offtake of that facility should be listed here.
Summer Max
Capacity or
Nameplate
(MW)
Provide the generator’s Net Generating Capability for the primary
energy source. This can be i) the net expected capacity, as
determined from a summer Capability Test performed in accordance
with the procedures on generator testing, Section 3.4 ii) the EIA-860
nameplate capacity for Wind, Solar, Run of River, and Energy Storage
Resources (ESR) located in the U.S. and iii) the nameplate capacity
for Wind, Solar, Run of River and ESR located outside of the U.S.
Winter Max
Capacity or
Nameplate
(MW)
Provide the generator’s Net Generating Capability for the primary
energy source. This can be i) the net expected capacity, as
determined from a winter Capability Test performed in accordance
with the procedures on generator testing, Section 3.4 ii) the EIA-860
nameplate capacity for Wind, Solar, Run of River, and ESR located in
the U.S. and iii) the nameplate capacity for Wind, Solar, Run of River
and ESR located outside of the U.S.

2 https://www.eia.gov/electricity/data/eia860/
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Description / Instructions
In-Service Date
Month-Year
Provide the month and year of the original in-service date (or
commercial operation date) that the resource became operational (if
possible, the operating year used in EIA-860 should be submitted for
all resources within the U.S.). For details on the format of the
submittal, refer to the Data Request Instruction Manual as posted in
an appropriate location on the WPP website.
Retirement
Date
Month-Year
Provide the month and year for resources that have been either
formally announced or marked for retirement.
State or
Province
Enter the state acronym where the resource is physically located. For
resources in Canada, enter the province.
County For resources in the U.S., enter the county where the resource is
located.
Inverter
Loading Ratio
(Only for Solar
and Wind)
For wind and solar only resources, enter the loading ratio of the
inverter compared to the nameplate of the resource. As an example,
if the nameplate of a solar resource is 150 MW and the inverter is
limited to 125 MW (oversizing of solar panels), then the ratio would
be 1.2 (150 / 125). If the nameplate of the resource is the same as
the inverter, or the loading ratio is not known, the provided loading
ratio would be 1.0.
ESR Duration
(Only for ESRs)
For ESRs, enter the maximum continuous number of hours for which
the ESR can be utilized at its maximum capacity.
Facility
Limitation
(Only for
Hybrid
Facilities) MW
For Hybrid Facilities, provide the maximum capability which the
combined amount of the component resources can output to the
system. This is typically based on the inverter limit before generation
is output to the system.
Comments Enter, if applicable, any additional comments about the submitted
information.

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Table 2. Additional Information Required for Resource Registration
Description / Instructions
Thermal Resources - North American Electric Reliability Corporation (NERC) Generating
Availability Data System (GADS) or equivalent data is required for all thermal resources.
For further details on the format of the submittal, refer to the Data Request Instruction
Manual as posted on the WPP website.
Wind, Run of River Hydro, Solar Resources – hourly output profiles for the last ten (10)
years or as much as is available. For further details on the format of the submittal, refer
to the Data Request Instruction Manual as posted on the WPP website.

The registration process for all Storage Hydro Qualifying Resources will require, but will
not be limited to, the items in Table 3, as follows:
Table 3. Storage Hydro Qualifying Resource Registration
Description / Instructions
Facility Name Plant name of the Storage Hydro Qualifying Resource. If possible,
utilize the EIA-860 plant name given for U.S. Storage Hydro
Qualifying Resources.
Unit ID The unique generator identification commonly used by plant
management. If possible, utilize the EIA-860 Generator ID given for
U.S. Storage Hydro Qualifying Resources.
Prime Mover Utilize the predetermined dropdown list of EIA-860 prime mover
identifiers.
Host Balancing
Authority
Provide the BAA location of the Storage Hydro Qualifying Resources.
Ownership or
Contracted
Percentage for
Participant
Enter the percentage owned or contracted by the Participant. This
should also include the percentage of any PPA where the Participant
has fully contracted for the capacity from a facility but would not
include a PPA with another Participant.
Individual
Monthly QCC
(MW)
QCC values by month (all months of the year) for all Storage Hydro
Qualifying Resources. The QCC of the Storage Hydro Qualifying
Resources is determined by Section 4 of this BPM.
In-Service Date
Month-Year
Provide the month and year of the original in-service or commercial
operation date that the Storage Hydro Qualifying Resource became
operational (if possible, the operating year used in EIA-860 should be
submitted for all Storage Hydro Qualifying Resources within the U.S.).
For planned Storage Hydro resources, enter the month and year the
Storage Hydro Qualifying Resource is projected to become
operational.
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Description / Instructions
Retirement
Date
Month-Year
Provide the month and year for resources that have been either
formally announced or marked for retirement.
State or
Province
Enter the state abbreviation where the Storage Hydro Qualifying
Resource is physically located. For Storage Hydro Qualifying
Resources in Canada, enter the province.
County For Storage Hydro Qualifying Resources in the U.S., enter the county
where the Storage Hydro Qualifying Resource is located.
Comments Enter, if applicable, any additional comments about the submitted
information.

3.3 Qualifying Resource Aggregation (Resources <1 MW)
Qualifying Resources that are less than 1 MW in size may be aggregated to obtain the
minimum 1MW registration requirement.
Qualifying Resources that are aggregated will need to have a common injection point of
capacity to the transmission system. Aggregations of generators at different distribution
substations may be allowed provided the generators are in the same , same zone (as
applicable by resource type), and are the same resource type.
For Qualifying Resources that are requested to be aggregated, the following information
should be provided to the PO.
 For the aggregated facility:
o Quantity of generators being aggregated
o Combined nameplate of generators being aggregated
o One-line diagram of the transmission/distribution system at which the
generators are located.
 For each generator being aggregated:
o Nameplate
o Location of power injection to the transmission system (substation)
o Supporting information for QCC evaluation.
This information will be provided to the PO in a form that will be provided with the
Advance Assessment data request workbook on the WPP website.
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3.4 Generator Testing
3.4.1 Background
Qualifying Resources must have Capability Tests and Operational Tests performed and
provided by the Participant, as applicable and in accordance with the guidelines
contained in this BPM. Capability Tests will be required for resources as detailed below.
All Qualifying Resources must perform annual Operational Tests.
3.4.2 Capability Testing
Capability Tests will be required for thermal resources, long duration storage resources,
and Demand Response resources (as defined in this BPM) with exceptions as noted in
this section.
For units that are required to perform Capability Tests, the Participant may choose
whether to use Capability Tests on a unit-by-unit basis or on a plant-level basis;
regardless of the approach, all units requiring a QCC must be tested (see bullet 3
below). Capability Test duration shall be a minimum of 1 hour. Once a qualifying
Capability Test is submitted to the PO at the FS Submittal Deadline, the 5-year
submittal window will be reset. The Capability Test may be performed at the
convenience of the Participant and can be completed more often than every 5 years.
The most recent testing data will be used to determine a generator’s QCC if a Capabilty
Test is performed between the Advanced Assessment and the FS Submittal.
For Storage Hydro, Run of River Hydro, Wind, Solar, and Energy Storage Resources, the
annual Operational Test will suffice as the Capability Test.
3.4.2.1 Capability Test Requirements for Thermal Resources
Capability Tests conducted for thermal resources are used as the base accredited value
to which unforced capacity (UCAP) calculations are applied (see Section 4.2) to
determine final QCC values. A thermal resource that is not subject to generator testing
requirements (i.e., are not subject to NERC MOD-025 requirements) may have its QCC
values determined in accordance with Section 4.2, Option 1, in lieu of performing the
Capability Test.
Capability Tests for thermal resources will be performed during the Summer Season and
must meet the testing requirements specified in this BPM. A resource may use its
Summer Season Capability Test value for both the Summer Season and the Winter
Season. If a unit has a greater Net Generating Capability for the Winter Season than for
the Summer Season, a separate Capability Test will need to be performed during the
Winter Season to claim the higher Net Generating Capability value.
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The following requirements must be met for a thermal resource Capability Test,
documentation of which will be provided to the PO at the time of the FS Submittal
Deadline:
1) Summer Capability Tests are to be conducted during a time when the ambient
dry-bulb temperature is no more than 10 degrees Fahrenheit below the station
ASHRAE Rated Ambient Temperature. At the time of testing, the most recent
version of the ASHRAE Fundamentals Handbook shall be utilized. If the dry-bulb
temperature exceeds 10 degrees below the ASHRAE Rated Ambient
Temperature, a penalty of 5% plus an additional 0.5% per degree for each
additional degree below 10 degrees, up to 20 degrees, will be applied to the
Capability Test result. A summer Capability Test shall not be performed in excess
of 20 degrees below the ASHRAE Rated Ambient Temperature. There is no
ambient temperature requirement for Winter Capability Tests.
2) The unit shall be brought to the desired test load and allowed to stabilize. Once
the test period has begun, only minor changes in unit controls shall be made as
required to maintain the unit in normal, steady-state operation.
3) The unit capability shall be determined separately for each generating unit in a
power plant where the input to the prime mover of the unit is independent of the
others. Units that are aggregated into a single Resource Registration and prefer
testing aligned with their registered resource and/or are dependent upon
common systems (i.e., fuel, steam supply, auxiliary equipment, transmission,
etc.) which restrict total output shall be tested simultaneously. Each unit shall be
assigned an individual capability by apportioning the combined capability among
the units.
4) The fuel used during testing shall be the type expected to be used during peak
load conditions.
5) The capability of a unit or plant obtained through non-typical operation (i.e.,
bypassing feedwater heaters, varying steam conditions, alternate control mode,
etc.) is acceptable.
3.4.2.2 Capability Testing of Long Duration Storage Resources
Capability Tests for Long Duration Storage resources are used as the base accredited
value to which unforced capacity (UCAP) calculations are applied (See Section 4.2) to
determine final QCC values. A Long Duration Storage resource that is not subject to
generator testing requirements (i.e., are not subject to NERC MOD-025 requirements)
may have its QCC values determined in accordance with Section 4.2, Option 1, in lieu of
performing the Capability Test. There are no temperature or timing requirements on the
Long Duration Storage Capability Test, other than the five year frequency.
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1) The unit shall be brought to the desired test load and allowed to stabilize. Once
the test period has begun, only minor changes in unit controls shall be made as
required to maintain the unit in normal, steady-state operation.
2) The unit capability shall be determined separately for each generating unit in a
plant where the input to the prime mover of the unit is independent of the
others. Units that are aggregated into a single Resource Registration and prefer
testing aligned with their registered resource and/or are dependent upon
common systems (i.e., fuel, steam supply, auxiliary equipment, transmission,
etc.) which restrict total output shall be tested simultaneously. Each unit shall be
assigned an individual capability by apportioning the combined capability among
the units.
3) The fuel used during testing shall be the type expected to be used during peak
load conditions.
4) The capability of a unit or plant obtained through non-typical operation (i.e.,
bypassing feedwater heaters, varying steam conditions, alternate control mode,
etc.) is acceptable.
3.4.2.3 Capability Testing of Demand Response Programs
A Capability Test for a Demand Response (DR) program registered as a Qualifying
Resource will be used to confirm the claimed capability of the DR program, as well as
the claimed duration of the load reduction (up to five hours). Capacity testing of the DR
program will consist of a sustained reduction in load attributable to the deployment of
the controllable and dispatchable program by the Participant for up to five hours. If a
DR program fails to achieve the claimed load reduction capability and duration during
the Capability Test, the DR program’s QCC will be determined using the tested values
instead. If the DR resource has a higher capacity value in one of the two Binding
Seasons, the Capability Test must be conducted during the Binding Season with the
higher capacity value; the DR resource does not need to be re-tested during the season
with a lower capacity value. There are no temperature requirements for the DR
Capacity Test.
As noted in Section 4.6, new DR programs, or the newly expanded portion of a DR
program, will be assigned a QCC of 50% of the expected capability. If the Participant
desires a higher QCC than 50% of the expected capability, Participant may conduct a
Capability Test outside of the expected peak season of the DR program. Testing
outside of the peak season will only be considered a Capability Test during the first year
of operation or during the expansion of an existing DR program. An Operational Test
shall then be performed during the upcoming Binding Season and reported to the PO
(see Section 3.4.3.6).
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3.4.2.4 Forced Outages Affecting Capability Testing
If a unit is due for a Capability Test, but unable to perform the Capability Test due to a
forced outage, a maintenance outage, or a forced de-rate, the most current Capability
Test results may be used, provided it is used only for the immediately succeeding
Summer Season and Winter Season. The unit will be required to perform an Operational
Test per the Operational Testing procedures (Section 3.4.3) before the next Summer
Season. For example, if a unit enters a forced outage while performing a Capability Test
and the repair for the unit cannot be completed until after the Summer Season, then
when the unit is repaired, an Operational Test must be completed. In that case, the
previous Capability Test will be used to satisfy the generator testing requirements for
the upcoming Summer Season FS Capacity Requirement workbook submittal. A
Capability Test must be performed in the next Summer Season for the next FS Capacity
Requirement workbook submittal. If the unit fails to complete the make-up Capability
Test, the unit cannot be claimed on the FS Capacity Requirement Submittal.
3.4.3 Operational Testing
3.4.3.1 Thermal Resources and Long Duration Storage
An Operational Test serves as an annual demonstration of the functional capability of a
Qualiying Resource to generate at a high level of its Net Generating Capability in the
upcoming Binding Season. This test must be completed in the 12-month period prior to
the FS Submittal due date and can be conducted within our outside of a Binding Season
(at Participant’s discretion). Test data shall be compiled and submitted via the FS
Submittal process, as outlined in BPM 108 Forward Showing Submittal. The Operational
Test must be conducted at a minimum of 90% of the Summer Net Generating
Capability. The Operational Test shall be conducted for a minimum of 1 hour , and for
thermal resources there are no Rated Ambient Temperature requirements for
Operational Tests. Any hour with the unit operating at or above 90% of the Net
Generating Capability may be deemed a successful Operational Test. In case of failure
to meet 90% of the Net Generating Capability, the resource can only claim what it can
achieve on the Operational Test (to which the UCAP calculations are applied – see
Section 4.2) for purposes of determining its QCC for the upcoming FS Submittal.
3.4.3.2 Storage Hydro Resources
An Operational Test serves as a verification that the resource can meet its QCC values
on a plant-level basis as determined by the Storage Hydro QCC methodology. This test
must be completed in the 12-month period directly prior to the FS Submittal due date
and can be conducted within or outside a Binding Season (at Participant’s discretion).
Test data shall be compiled and submitted via the FS Submittal process, as outlined in
BPM 108 Forward Showing Submittal. The Operational Test must achieve a minimum of
90% of the plant’s highest monthly QCC value from the FS Submittal being submitted.
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The Operational Test shall be conducted for a minimum of 1 hour and there are no
Rated Ambient Temperature requirements for Operational Tests. Any hour with the
plant operating at or above 90% of the highest monthly QCC submitted for the current
and previous Binding Season may be deemed a successful Operational Test. In case of
failure to meet 90% of the highest monthly QCC, the resource can claim no more than
what it achieved on the Operational Test for purposes of determining its QCC for the
upcoming FS Submittal.
Given that the Operational Test can be performed on any hour in a 12-month period,
the Operational Test should be scheduled (or re-scheduled) for a time when
outages/derates are not occurring. If one or more units were on outage or derated at
the time of the Operational Test, in order to claim the full QCC value provided by the
Storage Hydro QCC methodology, the Participant shall:
1) Demonstrate that the unit(s) out/derated at the time of the Operational Test
were offline/derated for more than 90 consecutive days of the 12 months
preceding the FS Submittal due date
2) Demonstrate that the unit was out/derated for the entirety of one of the months
with the three highest monthly QCC values for the plant
3) Provide operational data demonstrating the unit(s) performance on any hour
within the 12 months preceding the FS Submittal due date, or within the Cure
Period
4) Add the sustained hour-long operational value from the hour identified in (3) to
the Operational Test values.
If 90% of the highest monthly QCC value cannot be achieved after this addition, the
Participant can claim no more than the Operational Test (after the addition in (4)
above) for any month's QCC value.
3.4.3.3 ESRs
Operational Tests for ESRs should at least be conducted for the claimed duration of the
device – i.e., 2-hour, 4-hour, etc. An ESR must be able to achieve its full QCC as
determined in the QCC process for ESRs.
3.4.3.4 Run of River Hydro
Operational Tests shall be conducted at a minimum of 90% of the QCC for either
Binding Season. Any hour with the resource operating at or above 90% of the QCC may
be deemed a successful Operational Test. In case of failure to meet 90% of the QCC,
the resource can only claim what it can achieve on the Operational Test for purposes of
determining its QCC for the upcoming FS Submittal.
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3.4.3.5 Wind and Solar Qualifying Resources
Operational Tests shall be conducted at a minimum of 100% of the seasonal QCC for
either Binding Season. Any hour with the resource operating at or above 100% of the
QCC may be deemed a successful Operational Test. In case of failure to meet 100% of
the QCC, the resource can only claim what it can achieve on the Operational Test for
purposes of determining its QCC for the upcoming FS Submittal.
3.4.3.6 Demand Response Resources
An Operational Test will be conducted yearly during the Participant’s peak Binding
Season and at a minimum of 50% of the DR program’s claimed load reduction
capability (to avoid unnecessary disruption to the Participant’s customers). The duration
of an Operational Test shall be for a minimum of 1 hour.
3.4.4 New or Upgraded Resource Operational Testing
For newly installed resources and resources undergoing a physical or operational
modification which could impact the Net Generating Capability, design output may be
used for the first FS Submittal of the appropriate Binding Season to allow sufficient time
for Operational and Capability Tests to be conducted. For resources required to do so, a
Capability/Operational Test shall be performed in the Binding Season addressed by such
first FS Submittal, in order to establish the new Net Generating Capability for all
succeeding Binding Seasons.
3.4.5 Operational Testing for Late Registered Resources
Late Registered resources will be required to submit applicable generator operational
test reports as required by the resource fuel type. If a Participant demonstrates that it
has contracted for a resource not previously registered with the WRAP after the
Advance Assessment data request deadline for the Binding Season in which capacity is
being claimed to meet FS Capacity Requirements, the resource will be treated as if it
had tested at 95% of its Installed Capacity. A resource previously registered with the
WRAP that does not have any form of generator test results provided will be assumed
to have tested at 70% of its Installed Capacity. Resources not owned or operated by a
Participant that have test reports provided in a form other than the WRAP format, will
be evaluated by the PO and assigned an appropriate testing value based on
comparability to testing requirements established in this BPM; testing reports
determined not comparable will be assumed to have tested at 70% of Installed
Capacity. If the resource is newly installed or upgraded, the applicable section on new
and upgraded resources will be followed.
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3.4.6 Provision of Test Reports in the FS Submittal
Test reports will be provided to the PO in the FS Submittal (see BPM 108 Forward
Showing Submittal for more details). The QCC values for resources will be based on the
Capability Tests and/or Operational Tests provided in the FS Submittal.
4 Qualifying Capacity Contribution of Resources
4.1 Background
A resource will not be assigned a Resource QCC or counted toward Portfolio QCC unless
it is a Qualifying Resource. Qualifying Resources are those that, before they are
included in an FS Submittal, are first registered in the WRAP. A Participant seeking
registration of a resource must submit a request for registration providing the resource
information described in Section 3.
This section describes the methodology used to assign Resource QCCs to Qualifying
Resources when resources are registered through the Advance Assessment based on
resource type, as well as when Qualifying Resources of each resource type are
registered after the Advance Assessment data collection deadline (as a late registered
resource).
4.2 Thermal or Long Duration Storage Resources
For dispatchable resources that use conventional thermal fuels such as coal, gas,
biofuel, and nuclear, or long duration storage, the FS Program will use an Equivalent
Forced Outage Factor (EFOF) methodology to determine the QCC. Accreditation of non-
dispatchable thermal resources is covered in Section 4.8.2.
The seasonal QCC will be determined for each resource by applying the EFOFCCH to the
Net Generating Capability (or Installed Capacity) as determined in Section 3. The
Capacity Critical Hours (CCHs)3 will be used to determine the hours to be used in
calculating the EFOF for each resource. The EFOFCCH calculation, as set forth in the
formula in Section 4.2.1 below,will be performed for each year of the most recent six-
year historical look-back period. The equivalent outage factor is calculated by removing
the worst performing year (for each Summer and Winter Season) and then taking an
average of the remaining five years of data. The final calculated EFOFCCH will be applied
to the Net Generating Capability to calculate the QCC amount for the thermal generator
for the entire Binding Season.
Planned outages and any outage properly reported as “outside management control”
are not included in EFOFCCH calculations4.

3 CCH are calculated in accordance with BPM 104 Capacity Critical Hours.
4 https://www.nerc.com/pa/RAPA/gads/Pages/Data%20Reporting%20Instructions.aspx
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For resources new to the FS Program that do not have sufficient data over the historical
period used for determining a QCC, class average data for resources of similar size will
be used.
4.2.1 EFOFcch Equation

𝑬𝑭𝑶𝑭𝑪𝑪𝑯 𝟏 ∑𝑭𝑶𝑯𝒄𝒄𝒉 𝑬𝑭𝑫𝑯𝒄𝒄𝒉
𝒕𝒐𝒕𝒂𝒍𝑪𝑪𝑯
∗ 𝟏𝟎𝟎%
Where:
FOHcch is Forced Outage Hours occurring on CCHs,
EFDHcch is Equivalent Forced Derating Hours occurring on CCHs, and
Totalcch is total number of CCH for the timeframe of interest.
Definitions of FOHcch and EFDHcch can be found in Table 4.

Table 4. Definitions of FOH and EFDH
Definitions
FOHcch Sum of all CCH experienced during Forced Outages (U1, U2, and
U3) + Startup Failures5.
EFDHcch
Each forced derating (D1, D2, and D3)6 transformed into
equivalent full outage hour(s). This is calculated by multiplying
the actual duration of the derating (hours) by the size of the
reduction (MW) and dividing by the net maximum capacity.
These equivalent hour(s) are then summed by CCH.

𝐷𝑒𝑟𝑎𝑡𝑖𝑛𝑔 𝐻𝑜𝑢𝑟𝑠 ∗ 𝑆𝑖𝑧𝑒 𝑜𝑓 𝑅𝑒𝑑𝑢𝑐𝑡𝑖𝑜𝑛
𝑁𝑒𝑡 𝑀𝑎𝑥𝑖𝑚𝑢𝑚 𝐶𝑎𝑝𝑎𝑐𝑖𝑡𝑦

5 See NERC GADS reporting instructions at
https://www.nerc.com/pa/RAPA/gads/DataReportingInstructions/GADS_DRI_2023.pdf
6 Ibid.

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Additional Thermal QCC calculation considerations:
 Calculation is performed for each resource seasonally and for each historical
year. QCC will be assigned to each resource for the entire Binding Season.
 Six years of data will be used for the calculation. The worst performing Winter
Season and the worst performing Summer Season will be removed from the
calculations, allowing for a five-year average.
 Only forced outages or derates occurring during CCHs will be used to calculate
QCC. Outages during hours that are not deemed to be capacity critical will not
negatively impact QCC.
 All years (of the five years) will have equal weighting.
 Outside of Management Control outages as reported under NERC GADS
Appendix K7 (or equivalent) will be excluded from the calculation.
 For Participants relying on resource specific transactions external to the FS
Program, those Qualified Resources will follow the same QCC calculation for
thermal resources and the Participant will be responsible to make sure the
information is provided to the PO.
 The PO will break out each event by hour. If the NERC GADS (or equivalent)
data is reported in minutes, then the hour that contains the outage will be
equalized to account for the minutes. For example: if an outage starts on
6/1/2020 at 4:25, then the hour duration for that hour will be less than one since
the outage does not start at the top of the hour. The total hours for 6/1/2020 on
hour beginning 4:00 would be 0.583 ([60 Minutes – 25 minutes] / 60 minutes in
an hour).
 Diversity of time zones will be considered. Participants are required to list the
time zone that is appropriate for their respective data.
 When comparing the event hours to the CCH hour identification should be
consistent.

7 Appendix K of NERC GADS: https://www.nerc.com/pa/RAPA/gads/DataReportingInstructions/Appendix_K_Outside_Management_Control_2021_D
RI.pdf
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4.2.2 Late Registered Thermal Resources
If a Participant seeks to claim capacity from a thermal resource not registered at the
time of the Advance Assessment data request, the Participant may use the late
registered resource options (described generally in Section 3.2), choosing one of the
following approaches:
1) Demonstrate that the resource was acquired following the Advance Assessment
data request due date for the Binding Season in question, in which case the
resource will be permitted to use the class average QCC for thermal resources in
the program; or
2) Claim a decremented QCC of 70% of the class average for thermal resources in
the program.
4.2.3 Thermal Resources That Are Not Required to Report GADS Data
Certain thermal resources are not required to report GADS data. GADS data applies to
Generator Owners who are NERC registered with Qualified Resources that are 1)
connected to the Bulk Electric System and 2) are synchronous machines of 20MVA or
larger, or distributed generation facilities of 75MVA or larger. Smaller Qualified
Resources interconnected to the power system as well as Behind the Meter resources
may not be required to report GADS data. For these Qualified Resources, the Participant
will have two options to pursue in order to have QCC determined.
Option 1 – Historical Output. The first option will determine QCC based on the
monthly average performance of such resource during CCH. The Participant will
provide ten (10) years of historical hourly dispatch data. This data will be
provided with the data submittal (see BPM 101 Advance Assessment). A
workbook posted on the WPP website that contains the latest set of CCH will
allow the Participant to calcuate their QCC for the FS workbook. The workbook
will allow the Participant to calculate the QCC values taking the average of the
facility output during the CCH.
Option 2 – Historical Outage Evaluation – The second option will determine QCC
based on the monthly outage records provided by the Participant for the
resource in question. A workbook detailing what outage information is required
for a QCC calculation can be found posted on the WPP website. The Participant
will provide five (5) years of outage information as provided in the workbook.
The PO will determine the QCC of the resource in question using a methodology
similar to the EFOFCCH methodology applied to all thermal resources. An example
of the information required in the workbook is shown in Table 5.
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Table 5. Sample from Workbook for EFOF Calculation.
Date Time
Start
Binding
Season
(listed if
hour is a
CCH)
CCH?
(if the hour is
CCH, value is
‘TRUE’)
Was
resource on
forced
outage?
(1-yes) (0-
no)
Was the
outage
OMC8?
(1-yes) (0-
no)
Was the resource
forced de-rated? %
derate from
generating capability
(0-100%)
100% if on full
outage
Hourly
Forced
Outage
derate
(0-100%)
11/1/2014 0:00 Winter2015 FALSE 1 1 100% 100%
11/1/2014 1:00 Winter2015 FALSE 1 1 100% 100%
11/1/2014 2:00 Winter2015 FALSE 1 1 100% 100%
11/1/2014 3:00 Winter2015 FALSE 1 1 100% 100%
11/1/2014
12:00 Winter2015 FALSE 1 1 100% 100%

8 Outside of Management Control (OMC)
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Once all outage data information has been entered, the workbook calculates the EFOF
on the results summary tab.
For all Qualified Resources not providing GADS reporting data, the Participant will be
required to provide an attestation (provided in BPM 108 Forward Showing Submittal)
attesting that the resource is not subject to GADS reporting and the workbooks
submitted by the Participant are an accurate depiction of either the historical
performance or historical outage data of the resource.
4.3 Variable Energy Resources
The QCC for Variable Energy Resources (VERs), including but not limited to wind and
solar resources, will be determined for each month of the Binding Season through the
use of an ELCC analysis and a subsequent allocation process. Each Binding Season will
have its own ELCC analysis performed during the Advance Assessment and each
resource will be assigned a new QCC in advance of each Binding Season. Each Binding
Season’s ELCC analysis will have a scope document that will detail the study.
4.3.1 Source Data for Resources Under Study
In accordance with Section 3 and the Advance Assessment data submittal described in
BPM 101 Advance Assessement, the Participant will submit historical output data for
wind and solar resources that are requested to have QCC determined. A Participant
must submit three (3) and may submit up to ten (10) years of historical output data for
wind and solar resources.
For newer resources that do not have 10 years of operational data and historical
output, the Participant may provide engineering data from the wind or solar plant
operator. The PO will evaluate the data provided and determine its usefulness in the
ELCC process. The engineering data will need to provide synthesized outputs for the
facility for at least the most recent three (3) years of historical conditions. Otherwise,
the PO will use either synthesized data or average output data of other VER resources
in the appropriate VER Zone.
4.3.2 Late Registered VERs
If a Participant seeks to claim capacity from a VER not registered at the time of the
Advance Assessment data request, the Participant may use options for late registering a
resource, choosing one of the following approaches:
1) Demonstrate that the resource was acquired following the Advance Assessment
Data Request due date for the Binding Season in question and claim the average
ELCC of the VER Zone in which the resource is located, or
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2) Claim a decremented QCC of 70% the average ELCC in the VER Zone in which
the resource is located.
4.3.3 ELCC Study Process
The ELCC will be determined for the VERs in the WRAP Region. The ELCC study will
consist of analyses utilizing Loss of Load Expectation (LOLE) metrics to determine the
capacity provided by the VERs being analyzed. The LOLE benchmark metric to be used
in the ELCC accreditation study will be a one event in 10-year threshold.The ELCC of
VERs will be calculated first on a seasonal basis then later prorated to a monthly QCC
value. For the ELCC study, loss of load events will be tabulated during the Binding
Season months for determination of the 1-in-10 LOLE. Loss of load events that occur
outside of the Binding Season months will not go into the calculation of the capacity
value of VERs. Pure Capacity will be applied to the simulation process to derive the 0.1
day per year reliability threshold. If the resulting LOLE is greater than the 0.1 day per
year threshold, Pure Capacity will be added until the 0.1 threshold is achieved. If LOLE
is less than the 0.1 day per year threshold, negative Pure Capacity will be added until
the 0.1 threshold is achieved. The VER of interest will be excluded from the benchmark
system. All other VER types will be included. For example, if the wind resource type is
being analyzed, only wind will be excluded from the benchmark system.
The capacity calculated is designated in Figure 1 as Pure Capacity 1.
Figure 1. Diagram of system without renewable resources.

Next, a LOLE value for all wind generating resources will be determined, repeating the
steps described previously. The Pure Capacity value calculated is designated in Figure 2
as Pure Capacity 2.

Figure 2. Diagram of system with renewable resources.
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The difference between the results of these two steps is considered the ELCC QCC
value of the resources being studied.
𝑬𝑳𝑪𝑪 𝒐𝒇 𝑽𝑬𝑹 𝒖𝒏𝒅𝒆𝒓 𝒔𝒕𝒖𝒅𝒚 𝑷𝒖𝒓𝒆 𝑪𝒂𝒑𝒂𝒄𝒊𝒕𝒚 𝟏 𝑷𝒖𝒓𝒆 𝑪𝒂𝒑𝒂𝒄𝒊𝒕𝒚 𝟐

These processes are repeated to determine QCC for all weather years that are studied.
This process is repeated for summer and winter separately.
Zonal shapes have been developed for the LOLE study based on facility locations in
each VER Zone and correlated wind and solar activity with temperatures in those VER
Zones dating back to 1980. The ELCC study will be performed using the synthetic
shapes dating back to 1980, which are also used in the LOLE studies. The data provided
by the Participants will be used in the establishment of the synthetic shapes and used in
the allocation process for establishing the QCC of each VER resource as later outlined in
this BPM.
The PO will conduct the ELCC study by performing probabilistic simulations in a manner
that resources in the WRAP Region will be randomly forced out of service during each
hour of the study. Each simulation accounts for a different variation of forced outages
and load uncertainty for all hours of the year, similar to the LOLE study utilized to
establish the FS Planning Reserve Margin.
4.3.4 Determination of ELCC Within VER Zones
The ELCC study will determine the amount of capacity provided by all VERs (of the
specified type, e.g., wind) analyzed in the WRAP Region. The FS Program will employ
the VER zones for each VER type set forth in this BPM, as they may be revised from
time to time. Each VER of a given type will be assigned to one of the VER zones for that
type. ELCC studies will be performed for each VER zone (and VER type), calculating a
total capacity value for the resource of interest in that zone. The capacity calculated for
each VER zone will be allocated to VERs of that type in that zone on a pro-rata basis.
4.3.5 Determination of System Wide ELCC and Allocation to Individual VER Zones
To avoid over-accreditation of VERs the PO will conduct an ELCC study of the entire
WRAP Region and calculate a total capacity value for all VERs in the WRAP Region.
Additionally, all ESRs in a Subregion will be studied together. After all VER Zone
capacity totals (for each VER type) and the capacity totals of ESRs in each Subregion
have been determined, the sum of the VER Zone and ESR Subregion totals will be
compared to the regional VER plus ESR total. If the sum of the VER Zones and ESR
Subregion is greater than the regional total, all VER Zone and ESR Subregion totals will
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be scaled down until the totals match the regional total. Table 6 provides an example
of the calculations to determine total VER capacity.
Table 6. Example9 ELCC Study of WRAP Region to Calculate Total Capacity.
A study of two wind zones and two solar zones reveals the following
capacity values for each zone:
Wind Zone 1 Wind Zone 2 Solar Zone 1 Solar Zone 2 Total
1,000 MW 800 MW 700 MW 1,000 MW 3,500 MW
A study of the region reveals the following capacity value for the
re ion’s wind and solar:
Regional VERs
The zones will be recalculated as follows:
Wind Zone 1 Wind Zone 2 Solar Zone 1 Solar Zone 2 Total
1,000 *
(3,200/3,500)
800 *
(3,200/3,500)
700 *
(3,200/3,500)
1,000 *
(3,200/3,500)
914 MW 732 MW 640 MW 914 MW 3,200 MW
ESRs, which are discussed in more detail below (Section 4.4), are also included in the
system ELCC allocation and study.
4.3.6 VER Zones for Wind and Solar
WPP has established separate VER Zones for wind resources and solar resources, as
shown, respectively, in Figure 3 and Figure 4.
9 These examples are strictly illustrative, and do not set or limit any actual ELCC study results.
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Figure 3. Wind VER Zones Figure 4. Solar VER Zones
4.3.7 Allocation of ELCCs VERs
4.3.7.1 Allocation of System Wide ELCC On a Resource Basis
Once the ELCC has been determined for each VER Zone for each Binding Season, two
additional calculations must occur. The first step, which will occur before the system
ELCC adjustment, takes the ELCC seasonal values for each VER Zone and converts
them to a monthly basis for monthly QCC. Monthly QCC values for each VER Zone will
be calculated by shaping the seasonal ELCC value in accordance with aggregate
performance of all resources in the VER Zone during the CCH. Months that have higher
resource performance during the CCH will be allocated a higher portion of the ELCC
across the Binding Season. The QCC of each month will average to the seasonal ELCC
value. An example is given below in Table 7.
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Table 7. Example10 Monthly QCC Calculation for Wind VER Zone
Summer Season
June July Aug Sept
Average
Production on
CCH per month
Calculated from historical
performance data from wind
in this VER zone on a
monthly basis
120MW 95MW 90MW 130MW
Average
Production on
CCH across
season
Calculated from historical
performance data from wind
in this VER zone on a
seasonal basis
104MW
Monthly
Multiplier
Divides each month’s
production on CCH by the
seasonal average 115% 91% 87% 125%
Seasonal ELCC Value resulting from ELCC
study 100MW
Monthly QCC Multiplies the monthly
multiplier by the seasonal
ELCC value 115MW 91MW 87MW 125MW

The monthly QCC values for each VER Zone are then used to determine the system
ELCC value discussed in the section above.
The second step, which occurs after the system ELCC adjustment, will allocate the
monthly QCC values to each resource based on the individual resource’s performance
during the CCH.

𝑹𝒆𝒔𝒐𝒖𝒓𝒄𝒆 𝑬𝑳𝑪𝑪
𝑴𝒐𝒏𝒕𝒉𝒍𝒚 𝑬𝑳𝑪𝑪 𝑴𝑾 ∗ 𝑹𝒆𝒔𝒐𝒖𝒓𝒄𝒆 𝒂𝒗𝒆𝒓𝒂𝒈𝒆 𝒉𝒐𝒖𝒓𝒍𝒚 𝒏𝒆𝒕 𝒑𝒐𝒘𝒆𝒓 𝒐𝒖𝒕𝒑𝒖𝒕 𝒐𝒏 𝒕𝒐𝒑 𝟓% 𝒐𝒇 𝒏𝒆𝒕 𝒍𝒐𝒂𝒅 𝒉𝒐𝒖𝒓𝒔 𝑪𝑪𝑯
𝒁𝒐𝒏𝒆 𝒕𝒐𝒕𝒂𝒍 𝒂𝒗𝒆𝒓𝒂𝒈𝒆 𝒉𝒐𝒖𝒓𝒍𝒚 𝒏𝒆𝒕 𝒑𝒐𝒘𝒆𝒓 𝒐𝒖𝒕𝒑𝒖𝒕 𝒐𝒏 𝒕𝒐𝒑 𝟓% 𝒐𝒇 𝒏𝒆𝒕 𝒍𝒐𝒂𝒅 𝒉𝒐𝒖𝒓𝒔 𝑪𝑪𝑯

4.3.7.2 QCC Allocations for VERs with 3 Years or More of Operational Data
To allocate the ELCC MW to each resource, the PO will utilize the historical hourly data
for each resource provided by the Participant. For resources that have at least 3 years
of actual historical data, or at least 3 years of engineered data for newer resources, the

10 These examples are strictly illustrative, and do not set or limit any actual ELCC study results.
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PO will utilize the most recent 3 years (up to 10 years) of data when determining the
resource’s average hourly net power output.
4.3.7.3 QCC Allocations for New VERs or VERs with less than 3 Years of Operational Data
The PO will utilize the following method for newer VERs when determining the historical
average hourly net power output:
1) No less than three years will be utilized; and
2) A Participant (or resource owner) can supply synthesized data if at least 3 years
of actual data is not available, using:
a) Manufacturer’s engineering or performance data and actual weather
(preferably from on-site, but not from outside of 50-mile radius); or
b) Historical performance of similar resources within a 50-mile radius.
3) If three years of data is not provided by the Participant, either through synthetic
data or actual output, the resource will receive an ELCC value equal to the
product of a calculated class average ELCC percentage times the nameplate
capacity of the resource at issue. The PO will use the synthesized wind output
shape for the appropriate VER Zone to determine the class average ELCC
percentage.
As actual data is accrued, it will replace synthesized data as it becomes available (e.g.,
one year of actuals plus two years of synthesized; two years actuals plus one year
synthesized, then eventually three years of actuals). Once a new or repowered facility
has a full year of operational data the synthesized data for years two (2) and three (3)
will be evaluated for reasonableness. If the synthesized data significantly understated
or overstated the forecasted generation of the resource, the year 2 and 3 synthesized
data will be adjusted by the PO accordingly.
4.3.7.4 Determination of ELCC for Future VER Resources
It is understood that as VERs are added to a system, the capacity value provided by all
similar VERs as a function of the nameplate value of those resources will decrease. It
therefore becomes important for Participants to have an understanding of how VER
QCC values may change over time as the penetration of similar VERs increases.
After the QCC values of all existing and near-term planned VERs have been calculated
and allocated, additional ELCC studies will be performed to account for future VERs of
each type. These additional wind and solar resource amounts will be created by scaling
up the number of wind turbines (nameplate capacity) or solar photovoltaic panels in
each VER Zone. The PO will provide an ELCC curve, useful for guidance purposes on a
strictly non-binding basis, that can be used to estimate future capacity values for new
resources dependent upon the penetration of resources in that VER Zone.
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4.4 Energy Storage
The QCC for ESRs will be determined using the same general ELCC methodology used
for wind and solar resources (see Section 4.3) with any specific differences being
highlighted in this section and will be limited to ESRs that have the capability to store
energy equal to or greater than the energy output by the ESR over four continuous
hours (or longer) of operation. The ELCC study for each Binding Season will have a
scope document that details the analysis. ESRs with eight-hour or longer durations are
considered Long Duration Energy Storage (Section 4.2).
ESRs will be modeled as energy limited devices that will charge and discharge in
accordance with their equipment specifications. ESRs will be modeled to charge and
discharge in a preserve reliability mode, which means they will only be discharged to
mitigate potential loss of load when there is a lack of other resources available to serve
load. The dispatch of ESRs will be assumed for this modeling prupose to be scheduled
during high net load hours. Because of this schedule there may be hours where there is
uncertain generator performance and the ESRs may not be available to meet reliablity
needs.
4.4.1 ESR with Four‐ to Eight‐Hour Rating
Based on the four-hour minimum continuous time duration requirement, four-hour ESR
or ESRs with longer duration ratings will receive QCC values based on the four-hour
curve for the ESR penetration level of all ESR on the system at the time of the ELCC
assessment.
4.4.2 ESR with Rating Less than Four Hours
Based on the four-hour minimum continuous time duration requirement, ESRs with
ratings less than four hours will receive QCC values based on the four-hour curve for
the ESR penetration level of all ESRs on the system at the time of the ELCC assessment.
For example, two-hour rated ESRs would receive no more than 50% QCC value of a
four-hour ESR with the same maximum output.
4.4.3 Allocation of ELCC for ESRs
All ESRs in a WRAP defined Subregion will be studied together. All ESRs within a
Subregion will receive the average ELCC value of ESRs with a four-hour rating in that
Subregion, subject to the limitations outlined in Section 4.4.2. To ensure that over-
accreditation of ESRs does not occur, ESRs will be included in the ELCC study of all
VERs of the WRAP Region and a total combined capacity value for all VERs and ESRs in
the WRAP Region will be calculated. After all ESR Subregions and VER Zone capacity
totals have been determined, the sum of the VER Zone and ESR Subregion totals will be
compared to the WRAP Region VER total. If the sum of the VER Zones and ESR
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Subregion is greater than the regional total, all VER Zone and ESR Subregion totals will
be scaled down until the totals match the regional total.
4.4.4 Late Registered ESRs
If a Participant seeks to claim capacity from an ESR not registered at the time of the
Advance Assessment data request, the Participant may use the late registered resource
options (described generally in Section 3.2), choosing one of the following approaches:
1) Demonstrate that the resource was acquired following the Advance Assessment
data request due date for the Binding Season in question, in which case the
resource will be permitted to use the class average QCC for the ESRs within the
Subregion; or
2) Claim a decremented QCC of 70% of the class average for ESRs in the
Subregion.
4.5 Hybrid Facilities
Hybrid Facilities are resources that have at least two different fuels or technologies at a
common location where one of those resources is an ESR. The QCC for Hybrid
resources will be determined by applying the appropriate methodology to each
component of the facility and summing them and capping the total at the
interconnection limit. While hybrid resources are modeled as they would operate in the
LOLE study, determining QCC for combined hybrid resource is not performed due to the
inability to perform ELCC analysis for similar type resources.
4.6 Demand Response
DR can be utilized as a Qualifying Resource if it is greater than 1 MW in aggregate (see
Section 3.3) and can be demonstrated to be controllable and dispatchable by the
Participant or host utility. DR programs that register as Qualifying Resources will be
assigned a seasonal QCC value (one value for each Binding Season) and will need to
meet testing criteria and demonstrate load reduction (see Section 3.4.2.3) for a period
of up to five continuous hours. A DR program may be able to demonstrate load
reduction for a period beyond five continuous hours, but reductions of such duration go
beyond the typical duration of CCHs in a day, and so would not provide meaningful
QCC.11 Programs that are not able to provide five hours of load reduction will have their
load reduction prorated over the course of 5 hours for the determinatoin of QCC value.
Participants registering a DR Qualifying Resource must either i) demonstrate that the
DR program was not operated historically and has therefore not impacted the historical

11 WPP, WRAP Detailed Design, March 2023, p113. Available at: 2023-03-
10_WRAP_Draft_Design_Document_FINAL.pdf (westernpowerpool.org)
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load information provided by the Participant for determination of their P50 load value,
or ii) provide historical information about the operations of the DR program such that
the load reduction impacts of the DR program can be removed from the historical data
prior to determination of the P50 load value.
The QCC value of the DR Qualified Resource is determined by multiplying the maximum
load reduction (in MW) the resource is capable of sustaining by the number of hours
the resource can demonstrate such sustained load reduction capability (up to five
hours, maximum) divided by five.
A DR Qualifying Resource will be reflected in the FS Submittal as a capacity resource by
submitting it as a ‘Resource’ in the FS Submittal. As with all resources, the QCC value of
the DR Qualifying Resource will count toward a Participant meeting its FS Capacity
Requirement.
If DR does not meet the criteria of a Qualifying Resource, its contribution to the load
reduction may be captured in the historical data used to calculate the P50 load in the
FS.
4.6.1 New, Expanded, or Late Registered DR Resources
DR programs intended to be used as Qualifying Resources in the first year of operation
or expansion of an existing program or DR programs not registered at the time of the
Advance Assessment will be reported at 50% of the expected capability, unless
validated by testing the program to 100% of the claimed capability prior to the Binding
Season. See the section related to DR testing requirements (within Section 3.4.2) for
more information.
4.7 Hydro Resources
4.7.1 Storage Hydro (Also see Appendix A – Qualified Capacity Contribution for
Storage Hydro Resources)
QCCs for Storage Hydro resources are calculated by the Participant owners and the
results are provided to the PO for review, through the provision of the ‘results tab’ of
the workbook. The PO may ask the Participant for information from the Storage Hydro
QCC methodology, subject to limitations described in the Tariff, as part of the
verification and validation process. The Storage Hydro QCC methodology is based on
the ability of Storage Hydro to maximize output during the CCHs each day of the
historical record, subject to operational limitations and non-power constraints of each
plant. Limitations include available water in storage and all constraints that restrict the
use of the Net Generating Capability. These constraints include, but are not limited to,
discharge limits, tailrace and forebay elevation limits, and rate of change limits.
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The methodology considers each resource’s actual generation output, residual
generating capability, water in storage, reservoir levels (if applicable), upstream
discharge from Cascaded Dual Plants and plant constraints over the most recent 10-
year historical period. The QCC of the Storage Hydro resource is determined using a
calculation of how much historical actual generation could have been increased during
CCHs by increasing generation by utilizing water in storage each day of the historical
record, while respecting all operating constraints. The QCC is the monthly average of
this hypothetical increased generation during the CCHs, for the same month of the
historical record. The resulting QCC is determined as the average contribution to the
CCHs for each Winter Season and Summer Season over the previous 10 years. The
Storage Hydro QCC Workbook captures the aforementioned Storage Hydro QCC
methodology and is available for use by WRAP Participants. If historical data is not
available for 10 years, a comparable facility may be utilized or some other reasonable
approach that provides similar confidence in the computed QCC may be proposed by
the Participant and adopted at the discretion of the WPP. The Participant will provide all
required detailed data for the plant.
The detailed Storage Hydro QCC methodology can be found in Appendix A – Qualified
Capacity Contribution for Storage Hydro Resources of this BPM.
4.7.1.1 Late Registered Storage Hydro Resources
If a Participant seeks to claim capacity from a Storage Hydro resource not registered at
the time of the Advance Assessment data request, the Participant may use the late
registered resource options, choosing one of the following approaches:
1) Demonstrate that the resource was acquired following the Advance Assessment
data request due date for the Binding Season in question and utilize the
established Storage Hydro QCC methodology described above, or
2) Claim a decremented QCC of 70% of the average Storage Hydro QCCs in the
program.
4.7.2 Run of River Hydro
Run of River Hydro resources will have their QCC determined on the historical
performance of the resources during the CCH over the most recent 10-year period. The
data provided by the Participant in the Advance Assessment data submittal (see BPM
101 Advance Assessment) will be used for the determination of QCC.
If less than ten years of historical data is available for use in determining the QCC of a
Run of River Hydro plant, the PO will utilize the following method when determining the
historical average hourly net power output:
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1. No less than three years will be utilized.
2. A Participant (or resource owner) can supply synthesized data if at least 3 years
of actual data is not available, using:
a. Manufacturer’s engineering or performance data;
b. Actual water conditions (preferably from on-site, but not from a different
river); or
c. Historical performance of similar resources on the same river system.
3. If three years of data is not provided by the Participant, either through synthetic
data or actual output, the resource cannot receive a QCC value.
As actual data is accrued, it will replace synthesized data as it becomes available (e.g.,
one year of actuals plus two years of synthesized; two years actuals plus one year
synthesized, then eventually three years of actuals). Once a new or repowered facility
has a full year of operational data, the synthesized data for years two (2) and three (3)
will be evaluated for reasonableness. If the synthesized data significantly understated
or overstated the forecasted generation of the resource, the year 2 and 3 synthesized
data will be adjusted by the PO accordingly.
4.7.2.1 Late Registered Run of River Hydro Resources
If a Participant seeks to claim capacity from a Run of River Hydro resource not
registered at the time of the Advance Assessment data request, the Participant may use
the late registered resource options, choosing one of the following approaches:
1) Demonstrate that the resource was acquired following the Advance Assessment
data request due date for the Binding Season in question and execute the
methodology described above for Run of River Hydro Resources (for validation
by the PO), or
2) Claim a decremented QCC of 70% of the average Run of River Hydro QCCs in
the program.
4.8 Other Resources
4.8.1 Customer Resources
Resources that are generally located on the customer side of the meter can be included
in the FS Program. To be eligible as a Qualifying Resource, the customer resource must
1) be controllable and dispatchable by the Participant or host transmission operator,
and 2) not have already been used to modify the Participant’s load forecast (i.e.,
serving a portion or all of the load not included in load forecast). The resource shall
meet testing criteria applicable for resource type and will be awarded a QCC value
based on the appropriate methodolgy for the resource type. Customer resources
(behind the meter resources) can be aggregated to the 1 MW requirement to be
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considered a capacity resource, granted that they are in the same BAA, controllable and
dispatchable, and visible to the Ops Program.
4.8.2 Non‐Dispatchable, Must Take Resources
For resources that are either i) not dispatchable; or ii) require the purchaser of energy
from the resource to take energy as available from such resource, including but not
limited to a qualifying facility as defined under the Public Utility Regulatory Policies Act,
the QCC will be determined based on the monthly average performance of such
resource during CCH. The Participant will provide ten (10) years of historical hourly
dispatch data. This data may be provided within the Advance Assessment data
submittal (see BPM 101 Advance Assessement) or a workbook will be found at an
appropriate location on the WPP website that contains the latest set of CCH. The
workbook will allow the Participant to calculate the QCC values taking the average of
the facility output during the CCH.
If less than ten years of historical data is available for use in determining the QCC of a
non-dispatchable, must take resource, the PO will utilize the methodology described in
this BPM for the specific resource type. If the resource type is not covered in sections
4.2 thru 4.7 the PO will utilize the following method when determining the historical
average hourly net power output:
1. No less than three years will be utilized.
2. A Participant (or resource owner) can supply synthesized data if at least 3 years
of actual data is not available, using:
a. Manufacturer’s engineering or performance data;
b. Known or historical information about fuel availability;
c. Known or historical information about unit performance; or
d. Historical performance characteristics of similar resources.
3. If three years of data is not provided by the Participant, either through synthetic
data or actual output, the resource cannot receive a QCC value.

4.8.2.1 Late Registered Non-Dispatchable, Must Take Resources
If a Participant seeks to claim capacity from a non-dispatachable, must take resource
not registered at the time of the Advance Assessment data request, the Participant will
be required to execute the methodology described above for such resource (for
validation by the PO).
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Appendix A – Qualified Capacity Contribution for Storage Hydro Resources
5.1 Time Period Approach for Summer and Winter Season Requirements
Storage Hydro resources will use a “time period” approach to determine the QCC. A
time period approach consists of a historical look-back of the generation output during
CCH to determine how much capacity should be expected to be available during high
load periods in the future. While this approach is limited to a daily window for
determining available capacity, it does establish a common and transparent method for
determining the QCC for Storage Hydro Resources.
The following methodology would be used to determine the QCC value using the time
period approach described above, and Table A-1 summarizes the resource information
required to apply the methodology.:
 For each day found to contain one or more CCHs, the Storage Hydro resource
will be evaluated to determine the maximum available capacity for each CCH,
based on the conditions of the storage associated with the hydro resource on
that day.
 For each Storage Hydro resource, for each CCH, determine:
o Maximum generation output during the CCH.
o Useable water in storage at the end of the CCH.
o QCC for each hour, which would be the historical generation output plus
additional generation for capacity, up to the maximum generation
capability (adjusted for reservoir elevation head as applicable), taking into
account plant or unit-specific limitations (e.g., units on a common
penstock, transformer limitations, etc.) and the resource’s Equivalent
Demand Forced Outage Rate (EFORd).
o For calendar days with multiple CCHs, the QCC will be limited to the actual
historical generation, plus the useable energy in storage over that day.
Non-power operational constraints that limit the use of energy in storage.

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Table A-1. Resource information required to apply the methodology.
Information Needed Notes
Reservoir Elevation Range Min and Max – this may be seasonally
adjusted
Reservoir Storage Curve Indicating volume of water in storage
based on the reservoir elevation
Capacity as a Function of
Elevation
Plant maximum capacity at a given
forebay elevation
CCH Adjusted EFOFCCH or
Historical Outage Evaluation
Equivalent
Historical forced outage factor
Power as a Function of
Discharge For the “discharge method”
H/K as a Function of Elevation For the “elevation method”
Hourly Historical Data
 Actual generation
 Starting reservoir elevation
 Ending reservoir elevation



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From the information in Table A-1, the hourly values in Table A-2 can be estimated for
each CCH:
Table A-2. Hourly values that can be estimated.
Estimated Values Notes
Actual water in storage Using the elevation and storage (kcfsh or
cmsh) tables
Additional capacity available beyond the
actual generation Subject to forebay elevation restrictions
Cumulative additional generation
The running total of the additional
generation claimed in each CCH for the
day, used to deplete the elevation of the
reservoir to validate the feasibility of
using additional capacity in each CCH on
each calendar day
Hourly QCC The sum of the actual generation plus the
additional capacity available

The Storage Hydro capacity contribution towards the FS Capacity Requirement is
calculated by the resource owner as the simple average of the hourly QCC values in
each CCH over the ten years studied. These QCC values are averaged over each month
in each Binding Season to determine final monthly QCC values.
5.2 Treatment of Planned Outages
In addition to accounting for forced outages, the UCAP values used in the FS workbooks
may (at the Participant’s option), be reduced for planned outages. Planned outages that
are not included in the UCAP values will need to be planned in a manner similar to
thermal resources, meaning those planned outages will be taken from the Participant’s
surplus capacity in excess to the Participant’s FS Capacity Requirement.
Table A-3 and Table A-4 below illustrate the QCC calculation over a four-hour
consecutive period using the UCAP methodology and the UCAP + planned outages
methodology.

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Table A-3. Calculating QCC using UCAP = 125 MW.
Consecutive
CCHs
Historical
Generation
Historical
Storage
UCAP
(125
MW)
Draft to
Maximize
Capacity
Storage
After
Draft QCC
MW MWh MW MWh MWh MW
1 50 250 125 75 175 125
2 50 125 75 100 125
3 50 125 75 25 125
4 50 125 25 0 75
Storage empty after 25 MW draft 4-hour average 113

Table A-4. Calculating QCC using UCAP + Planned Outages = 100 MW.
Consecutive
CCHs
Historical
Generation
Historical
Storage
UCAP +
Planned
Outages
(100
MW)
Draft to
Maximize
Capacity
Storage
After
Draft QCC
MW MWh MW MWh MWh MW
1 50 250 100 50 200 100
2 50 100 50 150 100
3 50 100 50 100 100
4 50 100 50 50 100
A 25 MW planned outage decreased QCC by 13 MW 4-hour average 100

The four consecutive CCHs in Table A-3 illustrate how the QCC is limited due to
insufficient storage. In Table A-4, the UCAP is reduced by a 25 MW planned outage.
This reduced capacity requires less draft from storage in CCHs 1-3 to maximize the QCC
in those hours. This reduction in draft provides sufficient storage in CCH 4 to maximize
the QCC.
For FS purposes, planned outages may be included or excluded in the QCC calculation
at the choice of the Participant pursuant to the requirements in Section 16.2.8 of the
Tariff.
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5.3 Treatment of Non-Power Constraints
Each Participant is asked to review the methodology and incorporate the specific non-
power constraints that are applicable to the individual plants, thus reducing the QCC
value of each plant to a level that is believed to reflect the plants operational capability
for the upcoming Binding Season. This is done through creating additional constraint
logic in the spreadsheet that adds current and future non-power constraints to all 10
years’ worth of evaluation.
It is expected that Participants will include such non-power constraints that accurately
reflect their forecasted QCC capability, to facilitate reliance on Storage Hydro Resource
QCC values in the Operations Program and for other purposes.
5.4 Treatment of Cascaded and Coordinated Hydro Systems
A Cascaded Dual Plant methodology was also developed specifically for cascaded and
coordinated hydro systems. For cascaded hydro resources on the same river systems
that are operated in a coordinated manner, when determining the QCC, the useable
water in storage at the downstream resource could be enhanced by the operations at
the upstream resource, thereby maximizing the contribution of the combined cascaded
systems. The Cascaded Dual Plant methodology does not attempt to optimize use of
the upstream storage to maximize the combined QCC, but it does allow the downstream
plant to utilize the discharge from the upstream plant.
5.5 Form To Complete Storage Hydro Resource QCC
The Hydro QCC Workbook will be completed by the Participant. The workbook will be
located at an appropriate location on the WPP website.
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