Information Required for Small Power Production Facility If you indicated in line 1k that you are seeking qualifying small power production facility status for your facility, then you must respond to the items on this page. Otherwise, skip pages 11 through 15.
Certification of Compliance with Size Limitations
Pursuant to 18 C.F.R. § 292.204(a), the power production capacity of any small power production facility, together with the power production capacity of any other small power production facilities that use the same energy resource, are owned by the same person(s) or its affiliates, and are located at the same site, may not exceed 80 megawatts. To demonstrate compliance with this size limitation, or to demonstrate that your facility is exempt from this size limitation under the Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990 (Pub. L. 101-575, 104 Stat. 2834 (1990) as amended by Pub. L. 102-46, 105 Stat. 249 (1991)), respond to lines 8a through 8f below (as applicable).
Electric Generating Equipment
Electrical generating equipment will refer to all boilers, heat recovery steam generators, prime movers (any mechanical equipment driving an electric generator), electrical generators, photovoltaic solar panels, inverters, fuel cell equipment and/or other primary power generation equipment used in the facility, excluding equipment for gathering energy to be used in the facility. Each wind turbine on a wind farm and each solar panel in a solar facility is considered electrical generating equipment because each wind turbine and each solar panel is independently capable of producing electric energy.
Distance
The distance between two facilities is to be measured from the edge of the closest electrical generating equipment for which qualification or recertification is sought to the edge of the nearest electrical generating equipment of the other affiliated small power production qualifying facility using the same energy resource. An affiliated small power production QF located one mile or less from the instant facility is irrebuttably presumed to be at the same site. An affiliated small power production QF located more than one mile and less than 10 miles from the instant facility is rebuttably presumed to be at a separate site. An affiliated small power production QF located 10 miles or more from the instant facility is irrebuttably presumed to be located at a separate site. i
8a Identify affiliated small power production QFs located less than 10 miles from the electrical generating equipment of the instant facility that use the same energy resource and are held (with at least a 5 percent equity interest) by any of the entities identified in lines 5a or 5b or their affiliates. Specify the latitude and longitude coordinates for both the applicant and the affiliate small power production QF based on the nearest electrical generating equipment for each facility. Report coordinates in degrees (to three decimal places) as a positive number for east and north or a negative number for west and south. Use the following formula to convert to decimal degrees from degrees, minutes and seconds: decimal degrees = degrees + (minutes/60) + (seconds/3600).
See the "Geographic Coordinates" section on page 5 for help obtaining coordinates. The distances for each facility listed below will be automatically calculated from the reported coordinates. See www.ferc.gov/QF for more information on how this form calculates distance.
1)
Check here if no such facilities exist.
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Facility location
(city or county, state)
Root docket #
(if any)
Maximum net power
production capacity Common owner(s)
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0 i
8a Continued
Facility location
(city or county, state)
Root docket #
(if any)
Maximum net power
production capacity Common owner(s)
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
5)
4)
3)
2)
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Facility location
(city or county, state)
Root docket #
(if any)
Maximum net power
production capacity Common owner(s)
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
8a Continued
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
9)
8)
7)
6)
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
8a Continued
10)
Facility location
(city or county, state)
Root docket #
(if any) Common owner(s)
Maximum net power
production capacity
QF - kW
Coordinates (in degrees) and Distance (miles):
Distance
Latitude Choose +/- Longitude Choose +/-
Latitude Choose +/- Longitude Choose +/- miles0
Distance Calculator Specify the latitude and longitude coordinates for both the applicant and the affiliate small power production QF based on the nearest electrical generating equipment for each facility. Report coordinates in degrees (to three decimal places) as a positive number for east and north or a negative number for west and south.
Use the following formula to convert to decimal degrees from degrees, minutes and seconds: decimal degrees = degrees + (minutes/60) + (seconds/3600). See the "Geographic Coordinates" section on page 5 for help obtaining coordinates. The distances for each facility listed below will be automatically calculated from the reported coordinates. See www.ferc.gov/QF for more information on how this form calculates distance.
Closest electrical generating equipment for applicant's facility:
Closest electrical generating equipment for affiliate's facility:
Closest electrical generating equipment for applicant's facility (degrees):
miles0
DistanceClosest electrical generating equipment for affiliate's facility (degrees):
Check here and Use
the calculator below below to calculate distances based on facility coordinates. 8b You have the option below to assert preemptively that your facility is at a separate site from affiliated small power production QFs using the same energy resource more than one mile but less than 10 miles from your facility.
If additional space is needed, continue in the Miscellaneous section starting on page 24.
Pursuant to 18 C.F.R. § 292.204(a)(2)(i)(C), if affiliated small power producer qualifying facilities are more than one mile but less than 10 miles apart there is a rebuttable presumption that they are at separate sites. The factors listed below are examples of the factors that the Commission may consider in deciding whether small power production facilities that are owned by the same person(s) or its affiliates are located “at the same site”: (1) physical characteristics, including such common characteristics as: infrastructure, property ownership, property leases, control facilities, access and easements, interconnection agreements, interconnection facilities up to the point of interconnection to the distribution or transmission system, collector systems or facilities, points of interconnection, motive force or fuel source, off-take arrangements, connections to the electrical grid, evidence of shared control systems, common permitting and land leasing, and shared step-up transformers; and (2) ownership/other characteristics, including such characteristics as whether the facilities in question are: owned or controlled by the same person(s) or affiliated persons(s), operated and maintained by the same or affiliated entity(ies), selling to the same electric utility, using common debt or equity financing, constructed by the same entity within 12 months, managing a power sales agreement executed within 12 months of a similar and affiliated small power production qualifying facility (continued next page)...
continue in the Miscellaneous section starting on page 24 if additional space is needed.
Choose +/-LongitudeChoose +/-Latitude
Choose +/-LongitudeChoose +/-Latitude
8c The Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990 (Incentives Act) provides exemption from the size limitations in 18 C.F.R. § 292.204(a) for certain facilities that were certified prior to 1995.
Are you seeking exemption from the size limitations in 18 C.F.R. § 292.204(a) by virtue of the Incentives Act? No (skip lines 8d through 8f)Yes (continue at line 8d below) 8d Was the original notice of self-certification or application for Commission certification of the facility filed on or before December 31, 1994? NoYes
8e Did construction of the facility commence on or before December 31, 1999? NoYes 8f If you answered No in line 8e, indicate whether reasonable diligence was exercised toward the completion of the facility, taking into account all factors relevant to construction? NoYes If you answered Yes, provide a brief narrative explanation in the Miscellaneous section starting on page 24 of the construction timeline (in particular, describe why construction started so long after the facility was certified) and the diligence exercised toward completion of the facility.
Certification of Compliance with Size Limitations (continued)Certification of Compliance with Fuel Use Requirements
Pursuant to 18 C.F.R. § 292.204(b), qualifying small power production facilities may use fossil fuels, in minimal amounts, for only the following purposes: ignition; start-up; testing; flame stabilization; control use; alleviation or prevention of unanticipated equipment outages; and alleviation or prevention of emergencies, directly affecting the public health, safety, or welfare, which would result from electric power outages. The amount of fossil fuels used for these purposes may not exceed 25 percent of the total energy input of the facility during the 12-month period beginning with the date the facility first produces electric energy or any calendar year thereafter. 9a Certification of compliance with 18 C.F.R. § 292.204(b) with respect to uses of fossil fuel:
Applicant certifies that the facility will use fossil fuels exclusively for the purposes listed above. 9b Certification of compliance with 18 C.F.R. § 292.204(b) with respect to amount of fossil fuel used annually:
Applicant certifies that the amount of fossil fuel used at the facility will not, in aggregate, exceed 25 percent of the total energy input of the facility during the 12-month period beginning with the date the facility first produces electric energy or any calendar year thereafter. i
8b Continued
... (continued from previous page) in the same location, placed into service within 12 months of an affiliated small power production QF project's commercial operation date as specified in the power sales agreement, or sharing engineering or procurement contracts.
Information Required for Cogeneration Facility
If you indicated in line 1k that you are seeking qualifying cogeneration facility status for your facility, then you must respond to the items on pages 16 through 18. Otherwise, skip pages 16 through 18.General Cogeneration Information
Pursuant to 18 C.F.R. § 292.202(c), a cogeneration facility produces electric energy and forms of useful thermal energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes, through the sequential use of energy. Pursuant to 18 C.F.R. § 292.202(s), "sequential use" of energy means the following: (1) for a topping- cycle cogeneration facility, the use of reject heat from a power production process in sufficient amounts in a thermal application or process to conform to the requirements of the operating standard contained in 18 C.F.R. § 292.205(a); or (2) for a bottoming-cycle cogeneration facility, the use of at least some reject heat from a thermal application or process for power production.
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10a What type(s) of cogeneration technology does the facility represent? (check all that apply) Topping-cycle cogeneration Bottoming-cycle cogeneration i
10b To help demonstrate the sequential operation of the cogeneration process, and to support compliance with other requirements such as the operating and efficiency standards, include with your filing a mass and heat balance diagram depicting average annual operating conditions. This diagram must include certain items and meet certain requirements, as described below. You must check next to the description of each requirement below to certify that you have complied with these requirements.
Check to certify
compliance with
indicated requirement Requirement
Diagram must show orientation within system piping and/or ducts of all prime movers, heat recovery steam generators, boilers, electric generators, and condensers (as applicable), as well as any other primary equipment relevant to the cogeneration process.
Any average annual values required to be reported in lines 10b, 12a, 13a, 13b, 13d, 13f, 14a, 15b, 15d and/or 15f must be computed over the anticipated hours of operation.
Diagram must specify all fuel inputs by fuel type and average annual rate in Btu/h. Fuel for supplementary firing should be specified separately and clearly labeled. All specifications of fuel inputs should use lower heating values.
Diagram must specify average gross electric output in kW or MW for each generator.
Diagram must specify average mechanical output (that is, any mechanical energy taken off of the shaft of the prime movers for purposes not directly related to electric power generation) in horsepower, if any. Typically, a cogeneration facility has no mechanical output.
At each point for which working fluid flow conditions are required to be specified (see below), such flow condition data must include mass flow rate (in lb/h or kg/s), temperature (in °F, R, °C or K), absolute pressure (in psia or kPa) and enthalpy (in Btu/lb or kJ/kg). Exception: For systems where the working fluid is liquid only (no vapor at any point in the cycle) and where the type of liquid and specific heat of that liquid are clearly indicated on the diagram or in the Miscellaneous section starting on page 24, only mass flow rate and temperature (not pressure and enthalpy) need be specified. For reference, specific heat at standard conditions for pure liquid water is approximately 1.002 Btu/ (lb*R) or 4.195 kJ/(kg*K).
Diagram must specify working fluid flow conditions at input to and output from each steam turbine or other expansion turbine or back-pressure turbine.
Diagram must specify working fluid flow conditions at delivery to and return from each thermal application.
Diagram must specify working fluid flow conditions at make-up water inputs.
of Energy Output from Cogeneration Facilities
EPAct 2005 cogeneration facilities: The Energy Policy Act of 2005 (EPAct 2005) established a new section 210(n) of the Public Utility Regulatory Policies Act of 1978 (PURPA), 16 USC 824a-3(n), with additional requirements for any qualifying cogeneration facility that (1) is seeking to sell electric energy pursuant to section 210 of PURPA and (2) was either not a cogeneration facility on August 8, 2005, or had not filed a self-certification or application for Commission certification of QF status on or before February 1, 2006. These requirements were implemented by the Commission in 18 C.F.R. § 292.205(d). Complete the lines below, carefully following the instructions, to demonstrate whether these additional requirements apply to your cogeneration facility and, if so, whether your facility complies with such requirements.
11a Was your facility operating as a qualifying cogeneration facility on or before August 8, 2005? Yes No i 11b Was the initial filing seeking certification of your facility (whether a notice of self-certification or an application for Commission certification) filed on or before February 1, 2006? Yes No i If the answer to either line 11a or 11b is Yes, then continue at line 11c below. Otherwise, if the answers to both lines 11a and 11b are No, skip to line 11e below.
11c With respect to the design and operation of the facility, have any changes been implemented on or after February 2, 2006 that affect general plant operation, affect use of thermal output, and/or increase net power production capacity from the plant's capacity on February 1, 2006? Yes (continue at line 11d below)
No. Your facility is not subject to the requirements of 18 C.F.R. § 292.205(d) at this time. However, it may be subject to to these requirements in the future if changes are made to the facility. At such time, the applicant would need to recertify the facility to determine eligibility. Skip lines 11d through 11j. i
11d Does the applicant contend that the changes identified in line 11c are not so significant as to make the facility a "new" cogeneration facility that would be subject to the 18 C.F.R. § 292.205(d) cogeneration requirements? Yes.
Skip lines 11e through 11j.
Provide in the Miscellaneous section starting on page 24 a description of any relevant changes made to the facility (including the purpose of the changes) and a discussion of why the facility should not be considered a "new" cogeneration facility in light of these changes.
No. Applicant stipulates to the fact that it is a "new" cogeneration facility (for purposes of determining the applicability of the requirements of 18 C.F.R. § 292.205(d)) by virtue of modifications to the facility that were initiated on or after February 2, 2006. Continue below at line 11e. i
11e Will electric energy from the facility be sold pursuant to section 210 of PURPA? Yes. The facility is an EPAct 2005 cogeneration facility. You must demonstrate compliance with 18 C.F.R. § 292.205(d)(2) by continuing at line 11f below.
No. Applicant certifies that energy will not be sold pursuant to section 210 of PURPA. Applicant also certifies its understanding that it must recertify its facility in order to determine compliance with the requirements of 18 C.F.R. § 292.205(d) before selling energy pursuant to section 210 of PURPA in the future. Skip lines 11f through 11j.
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11f Is the net power production capacity of your cogeneration facility, as indicated in line 7g above, less than or equal to 5,000 kW?
Yes, the net power production capacity is less than or equal to 5,000 kW. 18 C.F.R. § 292.205(d)(4) provides a rebuttable presumption that cogeneration facilities of 5,000 kW and smaller capacity comply with the requirements for fundamental use of the facility's energy output in 18 C.F.R. § 292.205(d)(2). Applicant certifies its understanding that, should the power production capacity of the facility increase above 5,000 kW, then the facility must be recertified to (among other things) demonstrate compliance with 18 C.F.R. § 292.205(d)(2). Skip lines 11g through 11j.
No, the net power production capacity is greater than 5,000 kW. Demonstrate compliance with the requirements for fundamental use of the facility's energy output in 18 C.F.R. § 292.205(d)(2) by continuing on the next page at line 11g.
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of Energy Output from Cogeneration Facilities (continued) Lines 11g through 11k below guide the applicant through the process of demonstrating compliance with the requirements for "fundamental use" of the facility's energy output. 18 C.F.R. § 292.205(d)(2). Only respond to the lines on this page if the instructions on the previous page direct you to do so. Otherwise, skip this page. 18 C.F.R. § 292.205(d)(2) requires that the electrical, thermal, chemical and mechanical output of an EPAct 2005 cogeneration facility is used fundamentally for industrial, commercial, residential or institutional purposes and is not intended fundamentally for sale to an electric utility, taking into account technological, efficiency, economic, and variable thermal energy requirements, as well as state laws applicable to sales of electric energy from a qualifying facility to its host facility. If you were directed on the previous page to respond to the items on this page, then your facility is an EPAct 2005 cogeneration facility that is subject to this "fundamental use" requirement.
The Commission's regulations provide a two-pronged approach to demonstrating compliance with the requirements for fundamental use of the facility's energy output. First, the Commission has established in 18 C.F.R. § 292.205(d)(3) a "fundamental use test" that can be used to demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
Under the fundamental use test, a facility is considered to comply with 18 C.F.R. § 292.205(d)(2) if at least 50 percent of the facility's total annual energy output (including electrical, thermal, chemical and mechanical energy output) is used for industrial, commercial, residential or institutional purposes.
Second, an applicant for a facility that does not pass the fundamental use test may provide a narrative explanation of and support for its contention that the facility nonetheless meets the requirement that the electrical, thermal, chemical and mechanical output of an EPAct 2005 cogeneration facility is used fundamentally for industrial, commercial, residential or institutional purposes and is not intended fundamentally for sale to an electric utility, taking into account technological, efficiency, economic, and variable thermal energy requirements, as well as state laws applicable to sales of electric energy from a qualifying facility to its host facility.
Complete lines 11g through 11j below to determine compliance with the fundamental use test in 18 C.F.R. § 292.205(d)(3). Complete lines 11g through 11j even if you do not intend to rely upon the fundamental use test to demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
11g Amount of electrical, thermal, chemical and mechanical energy output (net of internal generation plant losses and parasitic loads) expected to be used annually for industrial, commercial, residential or institutional purposes and not sold to an electric utility MWh
11h Total amount of electrical, thermal, chemical and mechanical energy expected to be sold to an electric utility MWh
11i Percentage of total annual energy output expected to be used for industrial, commercial, residential or institutional purposes and not sold to a utility = 100 * 11g /(11g + 11h)
% 0
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11j Is the response in line 11i greater than or equal to 50 percent? Yes. Your facility complies with 18 C.F.R. § 292.205(d)(2) by virtue of passing the fundamental use test provided in 18 C.F.R. § 292.205(d)(3). Applicant certifies its understanding that, if it is to rely upon passing the fundamental use test as a basis for complying with 18 C.F.R. § 292.205(d)(2), then the facility must comply with the fundamental use test both in the 12-month period beginning with the date the facility first produces electric energy, and in all subsequent calendar years.
No. Your facility does not pass the fundamental use test.
Applicants providing a narrative explanation of why their facility should be found to comply with 18 C.F.R. § 292.205(d)(2) in spite of non-compliance with the fundamental use test may want to review paragraphs 47 through 61 of Order No. 671 (accessible from the Commission's QF website at www.ferc.gov/QF), which provide discussion of the facts and circumstances that may support their explanation. Applicant should also note that the percentage reported above will establish the standard that that facility must comply with, both for the 12-month period beginning with the date the facility first produces electric energy, and in all subsequent calendar years. See Order No. 671 at paragraph 51. As such, the applicant should make sure that it reports appropriate values on lines 11g and 11h above to serve as the relevant annual standard, taking into account expected variations in production conditions.
Instead, you must provide in the Miscellaneous
section starting on page 24 a narrative explanation of and support for why your facility meets the requirement that the electrical, thermal, chemical and mechanical output of an EPAct 2005 cogeneration facility is used fundamentally for industrial, commercial, residential or institutional purposes and is not intended fundamentally for sale to an electric utility, taking into account technological, efficiency, economic, and variable thermal energy requirements, as well as state laws applicable to sales of electric energy from a QF to its host facility.
Information Required for Topping-Cycle Cogeneration Facility If you indicated in line 10a that your facility represents topping-cycle cogeneration technology, then you must respond to the items on pages 19 and 20. Otherwise, skip pages 19 and 20.Usefulness of Topping-Cycle Thermal Output
The thermal energy output of a topping-cycle cogeneration facility is the net energy made available to an industrial or commercial process or used in a heating or cooling application. Pursuant to sections 292.202(c), (d) and (h) of the Commission's regulations (18 C.F.R. §§ 292.202(c), (d) and (h)), the thermal energy output of a qualifying topping- cycle cogeneration facility must be useful. In connection with this requirement, describe the thermal output of the topping-cycle cogeneration facility by responding to lines 12a and 12b below. i
12a Identify and describe each thermal host, and specify the annual average rate of thermal output made available to each host for each use. For hosts with multiple uses of thermal output, provide the data for each use in separate rows.
Name of entity (thermal host)
taking thermal output
Thermal host's relationship to facility;
Thermal host's use of thermal output
Average annual rate of
thermal output
attributable to use (net of
heat contained in process
return or make-up water)
1) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
2) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
3) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
4) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
5) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
6) Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
Check here and continue in the Miscellaneous section starting on page 24 if additional space is needed 12b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each use of the thermal output identified above. In some cases, this brief description is sufficient to demonstrate usefulness.
However, if your facility's use of thermal output is not common, and/or if the usefulness of such thermal output is not reasonably clear, then you must provide additional details as necessary to demonstrate usefulness. Your application may be rejected and/or additional information may be required if an insufficient showing of usefulness is made. (Exception: If you have previously received a Commission certification approving a specific use of thermal output related to the instant facility, then you need only provide a brief description of that use and a reference by date and docket number to the order certifying your facility with the indicated use. Such exemption may not be used if any change creates a material deviation from the previously authorized use.) If additional space is needed, continue in the Miscellaneous section starting on page 24.
Efficiency Value Calculation
Applicants for facilities representing topping-cycle technology must demonstrate compliance with the topping- cycle operating standard and, if applicable, efficiency standard. Section 292.205(a)(1) of the Commission's regulations (18 C.F.R. § 292.205(a)(1)) establishes the operating standard for topping-cycle cogeneration facilities:
the useful thermal energy output must be no less than 5 percent of the total energy output. Section 292.205(a)(2) (18 C.F.R. § 292.205(a)(2)) establishes the efficiency standard for topping-cycle cogeneration facilities for which installation commenced on or after March 13, 1980: the useful power output of the facility plus one-half the useful thermal energy output must (A) be no less than 42.5 percent of the total energy input of natural gas and oil to the facility; and (B) if the useful thermal energy output is less than 15 percent of the total energy output of the facility, be no less than 45 percent of the total energy input of natural gas and oil to the facility. To demonstrate compliance with the topping-cycle operating and/or efficiency standards, or to demonstrate that your facility is exempt from the efficiency standard based on the date that installation commenced, respond to lines 13a through 13l below.
If you indicated in line 10a that your facility represents both topping-cycle and bottoming-cycle cogeneration technology, then respond to lines 13a through 13l below considering only the energy inputs and outputs attributable to the topping-cycle portion of your facility. Your mass and heat balance diagram must make clear which mass and energy flow values and system components are for which portion (topping or bottoming) of the cogeneration system.
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13a Indicate the annual average rate of useful thermal energy output made available to the host(s), net of any heat contained in condensate return or make-up water Btu/h 13b Indicate the annual average rate of net electrical energy output kW
13c Multiply line 13b by 3,412 to convert from kW to Btu/h Btu/h0 i
13d Indicate the annual average rate of mechanical energy output taken directly off of the shaft of a prime mover for purposes not directly related to power production (this value is usually zero)
hp
13e Multiply line 13d by 2,544 to convert from hp to Btu/h Btu/h0 i
13f Indicate the annual average rate of energy input from natural gas and oil Btu/h
13g Topping-cycle operating value = 100 * 13a / (13a + 13c + 13e) %0
13h Topping-cycle efficiency value = 100 * (0.5*13a + 13c + 13e) / 13f %0
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13i Compliance with operating standard: Is the operating value shown in line 13g greater than or equal to 5%? Yes (complies with operating standard) No (does not comply with operating standard) 13j Did installation of the facility in its current form commence on or after March 13, 1980? Yes. Your facility is subject to the efficiency requirements of 18 C.F.R. § 292.205(a)(2). Demonstrate compliance with the efficiency requirement by responding to line 13k or 13l, as applicable, below.
No. Your facility is exempt from the efficiency standard. Skip lines 13k and 13l. i
13k Compliance with efficiency standard (for low operating value): If the operating value shown in line 13g is less than 15%, then indicate below whether the efficiency value shown in line 13h greater than or equal to 45%:
Yes (complies with efficiency standard) No (does not comply with efficiency standard) 13l Compliance with efficiency standard (for high operating value): If the operating value shown in line 13g is greater than or equal to 15%, then indicate below whether the efficiency value shown in line 13h is greater than or equal to 42.5%:
Yes (complies with efficiency standard) No (does not comply with efficiency standard)
Information Required for Bottoming-Cycle Cogeneration Facility If you indicated in line 10a that your facility represents bottoming-cycle cogeneration technology, then you must respond to the items on pages 21 and 22. Otherwise, skip pages 21 and 22.Usefulness of Bottoming-Cycle Thermal Output
The thermal energy output of a bottoming-cycle cogeneration facility is the energy related to the process(es) from which at least some of the reject heat is then used for power production. Pursuant to sections 292.202(c) and (e) of the Commission's regulations (18 C.F.R. § 292.202(c) and (e)) , the thermal energy output of a qualifying bottoming- cycle cogeneration facility must be useful. In connection with this requirement, describe the process(es) from which at least some of the reject heat is used for power production by responding to lines 14a and 14b below. i
14a Identify and describe each thermal host and each bottoming-cycle cogeneration process engaged in by each host. For hosts with multiple bottoming-cycle cogeneration processes, provide the data for each process in separate rows.
Name of entity (thermal host)
performing the process from
which at least some of the
reject heat is used for power
production
Thermal host's relationship to facility;
Thermal host's process type
Has the energy input to
the thermal host been
augmented for purposes
of increasing power
production capacity?
(if Yes, describe on p. 24)
1) Select thermal host's relationship to facility
Select thermal host's process type
Yes No
2) Select thermal host's relationship to facility
Select thermal host's process type
Yes No
3) Select thermal host's relationship to facility
Select thermal host's process type
Yes No
Check here and continue in the Miscellaneous section starting on page 24 if additional space is needed 14b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each process identified above. In some cases, this brief description is sufficient to demonstrate usefulness. However, if your facility's process is not common, and/or if the usefulness of such thermal output is not reasonably clear, then you must provide additional details as necessary to demonstrate usefulness. Your application may be rejected and/or additional information may be required if an insufficient showing of usefulness is made. (Exception: If you have previously received a Commission certification approving a specific bottoming-cycle process related to the instant facility, then you need only provide a brief description of that process and a reference by date and docket number to the order certifying your facility with the indicated process. Such exemption may not be used if any material changes to the process have been made.) If additional space is needed, continue in the Miscellaneous section starting on page 24.
Efficiency Value Calculation
Applicants for facilities representing bottoming-cycle technology and for which installation commenced on or after March 13, 1990 must demonstrate compliance with the bottoming-cycle efficiency standards. Section 292.205(b) of the Commission's regulations (18 C.F.R. § 292.205(b)) establishes the efficiency standard for bottoming-cycle cogeneration facilities: the useful power output of the facility must be no less than 45 percent of the energy input of natural gas and oil for supplementary firing. To demonstrate compliance with the bottoming-cycle efficiency standard (if applicable), or to demonstrate that your facility is exempt from this standard based on the date that installation of the facility began, respond to lines 15a through 15h below.
If you indicated in line 10a that your facility represents both topping-cycle and bottoming-cycle cogeneration technology, then respond to lines 15a through 15h below considering only the energy inputs and outputs attributable to the bottoming-cycle portion of your facility. Your mass and heat balance diagram must make clear which mass and energy flow values and system components are for which portion of the cogeneration system (topping or bottoming).
15a Did installation of the facility in its current form commence on or after March 13, 1980? Yes. Your facility is subject to the efficiency requirement of 18 C.F.R. § 292.205(b). Demonstrate compliance with the efficiency requirement by responding to lines 15b through 15h below.
No. Your facility is exempt from the efficiency standard. Skip the rest of page 22. 15b Indicate the annual average rate of net electrical energy output kW
15c Multiply line 15b by 3,412 to convert from kW to Btu/h Btu/h0
i
15d Indicate the annual average rate of mechanical energy output taken directly off of the shaft of a prime mover for purposes not directly related to power production (this value is usually zero)
hp
15e Multiply line 15d by 2,544 to convert from hp to Btu/h Btu/h0 i
15f Indicate the annual average rate of supplementary energy input from natural gas or oil Btu/h
15g Bottoming-cycle efficiency value = 100 * (15c + 15e) / 15f %0 i
15h Compliance with efficiency standard: Indicate below whether the efficiency value shown in line 15g is greater than or equal to 45%:
Yes (complies with efficiency standard) No (does not comply with efficiency standard) FERC Form 556 Page 23 - All Facilities
Certificate of Completeness, Accuracy and Authority
Applicant must certify compliance with and understanding of filing requirements by checking next to each item below and signing at the bottom of this section. Forms with incomplete Certificates of Completeness, Accuracy and Authority will be rejected by the Secretary of the Commission.
Signer identified below certifies the following: (check all items and applicable subitems) He or she has read the filing, including any information contained in any attached documents, such as cogeneration mass and heat balance diagrams, and any information contained in the Miscellaneous section starting on page 24, and knows its contents.
He or she has provided all of the required information for certification, and the provided information is true as stated, to the best of his or her knowledge and belief.
He or she possess full power and authority to sign the filing; as required by Rule 2005(a)(3) of the Commission's Rules of Practice and Procedure (18 C.F.R. § 385.2005(a)(3)), he or she is one of the following: (check one) The person on whose behalf the filing is made
An officer of the corporation, trust, association, or other organized group on behalf of which the filing is made An officer, agent, or employe of the governmental authority, agency, or instrumentality on behalf of which the filing is made
A representative qualified to practice before the Commission under Rule 2101 of the Commission's Rules of Practice and Procedure (18 C.F.R. § 385.2101) and who possesses authority to sign He or she has reviewed all automatic calculations and agrees with their results, unless otherwise noted in the Miscellaneous section starting on page 24.
He or she has provided a copy of this Form 556 and all attachments to the utilities with which the facility will interconnect and transact (see lines 4a through 4d), as well as to the regulatory authorities of the states in which the facility and those utilities reside. See the Required Notice to Public Utilities and State Regulatory Authorities section on page 4 for more information.
Provide your signature, address and signature date below. Rule 2005(c) of the Commission's Rules of Practice and Procedure (18 C.F.R. § 385.2005(c)) provides that persons filing their documents electronically may use typed characters representing his or her name to sign the filed documents. A person filing this document electronically should sign (by typing his or her name) in the space provided below.
Your Signature
Jacob Pollack
General Counsel
Your address
101 South Tyron Street, 5th Floor
Charlotte, NC 28280
Date
1/6/2026
Audit Notes
Commission Staff Use Only:
FERC Form 556 Page 24 - All Facilities
Miscellaneous
Use this space to provide any information for which there was not sufficient space in the previous sections of the form to provide. For each such item of information clearly identify the line number that the information belongs to. You may also use this space to provide any additional information you believe is relevant to the certification of your facility.
Your response below is not limited to one page. Additional page(s) will automatically be inserted into this form if the length of your response exceeds the space on this page. Use as many pages as you require.
Section 1l (continued):
Applicant is filing this recertification to refresh ownership information in section 5b to report an internal reorganization (Reorganization) that occurred on November 21, 2025.
The Reorganization has no effect on the QF status of the facility recertified herein (Facility). Additionally, Applicant has refreshed the contact information in sections 1 and 2b.
Section 5b (continued):
From time-to-time, the entities identified in section 5b may hold their interests through one or more subsidiaries, all of which are affiliates of Brookfield Corporation and Brookfield Asset Management Ltd. (BAM Ltd., and together with Brookfield Corporation, Brookfield).
As shown in section 5b, Applicant is an indirect wholly owned subsidiary of Symphony Breeze, LLC (Symphony Breeze). Symphony Breeze Holdings, LLC (Symphony Breeze Holdings) directly owns all of the voting membership interests in Symphony Breeze and is the managing member of Symphony Breeze. Symphony Breeze also has non-voting membership interests, which are owned by a passive investor with only limited consent rights similar to those recognized by the Commission in AES Creative Resources, L.P., 129 FERC ¶ 61,239 at n.10 & P21 (2009).
Symphony Breeze Holdings is a wholly owned direct subsidiary of Symphony Breeze Borrower LLC, which is a wholly owned direct subsidiary of Deriva Energy, LLC, which is a wholly owned direct subsidiary of Deriva Energy Holding Company, LLC (Deriva Energy Holding).
Deriva Energy Holding is a wholly owned direct subsidiary of Deriva Energy Holdco II LLC, which is a wholly owned direct subsidiary of Deriva Energy Holdco I LLC, which in turn is a wholly owned direct subsidiary of Deriva Energy Parent LLC (Deriva Energy Parent).
Deriva Energy Parent is owned by BEP BIF V Hollywood LLC (BEP BIF V Hollywood), BIF V Hollywood Carry II, L.P. (BIF V Hollywood Carry II), and BIF V Hollywood Carry III, L.P. (BIF V Hollywood Carry). Upstream ownership of BEP BIF V Hollywood, BIF V Hollywood Carry II, and BIF V Hollywood Carry is described below.
BEP BIF V Hollywood. BEP BIF V Hollywood is a wholly-owned direct subsidiary of BEP BIF V Hollywood AIV LLC, which is a wholly-owned direct subsidiary of Deriva US Holdco LLC, which is a wholly-owned direct subsidiary of Brookfield Renewable EU Limited, which is a wholly-owned direct subsidiary of Brookfield BRP Europe Holdings (Bermuda) Limited, which in turn is a wholly-owned direct subsidiary of Brookfield Renewable Energy L.P. (BRELP).
Through wholly-owned subsidiaries, Brookfield Asset Management ULC (BAM ULC) owns the general partnership interest in BRELP. BAM ULC is owned by BAM Ltd., which is the principal holding entity for Brookfield’s asset management business and a subsidiary of Brookfield Corporation. The limited partnership interest in BRELP is owned by Brookfield Renewable Partners L.P. (BEP). BEP is a Bermuda limited partnership that is publicly traded on the Toronto Stock Exchange and New York Stock Exchange, under the symbols BEP.
UN and BEP, respectively. Brookfield Renewable Power Inc., an indirect subsidiary of Brookfield Corporation, indirectly owns the 0.01% general partnership interest in BEP and has sole responsibility and authority for the management and control of BEP. The limited partnership units in BEP are passive non-voting securities. BRELP also has redeemable FERC Form 556 Page 25 - All Facilities
Miscellaneous (continued)
exchangeable partnership units, owned by indirect subsidiaries of Brookfield Corporation, that are exchangeable for passive BEP limited partnership units.
BIF V Hollywood Carry II. The general partnership interest in BIF V Hollywood Carry II is owned by BIF V Carry US Splitter LP (BIF V Carry US Splitter), which in turn is managed and controlled by a general partner that is a wholly-owned indirect subsidiary of BAM ULC. As explained above, BAM ULC is owned by Brookfield. Each of BIF V Hollywood Carry II and BIF V Carry US Splitter also has limited partnership interests with only limited consent rights similar to those recognized by the Commission in AES Creative Resources, L.P., 129 FERC ¶ 61,239 at n.10 & P21 (2009) (AES Creative Resources). These limited partnership interests do not provide any right to participate in the management or conduct of BIF V Hollywood Carry II or BIF V Carry US Splitter.
BIF V Hollywood Carry. The general partnership interest in BIF V Hollywood Carry is owned by BIF V Carry US Splitter, which is described above. BIF V Hollywood Carry also has limited partnership interests with only limited consent rights similar to those recognized by the Commission in AES Creative Resources, L.P., 129 FERC ¶ 61,239 at n.10 & P21 (2009) (AES Creative Resources). These limited partnership interests do not provide any right to participate in the management or conduct of BIF V Hollywood Carry.
Section 8a (continued):
Applicant's affiliates through Brookfield own portfolios of QFs that are comprised of approximately 4,000 separately-interconnected, individual residential rooftop solar photovoltaic systems with maximum net power production capacities of 20kW or less (Residential PV Systems). Although certain Residential PV Systems are within 10 miles of the facility that is the subject of this recertification, the Commission has granted a request for waiver of the requirement to include such facilities in Section 8a.
Brookfield Asset Management Inc., 176 FERC ¶ 61,039 at P 25 (2021). Accordingly, no Residential PV Systems are listed in Section 8a of this form.