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Asset Appendix Report

: Cedar Creek II, LLC : C002169
: 12963 :
: : 8/16/2023
: John L. Criner
Generation Assets
ID Filing Entity
and its Energy Affiliates		 Docket Number
Where MBR Granted		 Generation
Name		 Owned
By		 Controlled
By		 Date Control
Transferred		 Market / Balancing
Authority Area		 Geographic
Region		 In-Service
Date		 Plant Code Generator ID Unit Code Amount Attributed to
Entity and Affiliates		 Capacity Rating
Used in Filing (MW)		 Capacity Rating Methodology Used:
Nameplate, Seasonal, 5-yr Unit,
5-yr EIA, Alternative		 End Note Number
(Enter text in End Note Tab)
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 41 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 42 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 43 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 44 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 45 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 46 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 47 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 48 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN6 0.30 0.30
Cedar Creek II, LLC ER08-1323-000 Fowler Ridge Wind Farm LLC 1/1/1960 PJM Northeast 2009-03 56777 FIB 100.00 100.00
Cedar Creek II, LLC ER08-1323-000 Fowler Ridge Wind Farm LLC 1/1/1960 PJM Northeast 2009-03 56777 FIA 201.30 201.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 6/1/1993 PJM Northeast 1993-06 54766 GEN9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN13 0.30 0.30
Cedar Creek II, LLC ER01-1764-000 Archbald Power Station 5/1/2001 PJMF Northeast 2001-05 50279 Gen2 60.50 60.50
Cedar Creek II, LLC ER05-717-000 Spring Canyon 1/1/1960 PSCO Northwest 2006-02 56320 1 60.00 60.00 The “Date Control Transferred” with respect to Spring Canyon Energy LLC’s (“Spring Canyon”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Spring Canyon’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Spring Canyon has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 60 MW.
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN15 0.30 0.30
Cedar Creek II, LLC ER05-721-000 Judith Gap Wind Energy Center 1/1/1960 NWMT Northwest 2005-12 56377 1 135.00 135.00 The “Date Control Transferred” with respect to Judith Gap Energy LLC’s (“Judith Gap”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Judith Gap’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Judith Gap has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix.
Cedar Creek II, LLC ER04-374-000 Buffalo Mountain Energy Center 1/1/1960 TVA Southeast 2004-12 56493 4 27.00 27.00 The “Date Control Transferred” with respect to Invenergy TN LLC’s (“Invenergy TN”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Invenergy TN’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Invenergy TN has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 27 MW.
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN17 0.30 0.30
Cedar Creek II, LLC ER06-230-000 Wolverine Creek 1/1/1960 PACE Northwest 2006-02 56301 1 64.50 64.50 The “Date Control Transferred” with respect to Wolverine Creek Energy LLC’s (“Wolverine Creek”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Wolverine Creek’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Wolverine Creek has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix.
Cedar Creek II, LLC ER07-810-000 Grays Harbor Energy Facility 1/1/1960 BPAT Northwest 2008-05 7999 CT1 CC01 188.00 188.00 The “Date Control Transferred” with respect to Grays Harbor Energy LLC’s (“Grays Harbor”) ownership of unit CT1 described in this row of the asset appendix (which is part of the Grays Harbor Energy Facility identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Grays Harbor Energy Facility began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grays Harbor has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit CT1 of the Grays Harbor Energy Facility is the winter seasonal rating; the summer seasonal rating for this generating unit is 151 MW and the nameplate rating for this generating unit is 198.9 MW.
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN29 0.30 0.30
Cedar Creek II, LLC ER07-810-000 Grays Harbor Energy Facility 1/1/1960 BPAT Northwest 2008-05 7999 CT2 CC01 190.00 190.00 The “Date Control Transferred” with respect to Grays Harbor Energy LLC’s (“Grays Harbor”) ownership of unit CT2 described in this row of the asset appendix (which is part of the Grays Harbor Energy Facility identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation assets began generating test power), however, because this unit of the Grays Harbor Energy Facility began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grays Harbor has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit CT2 of the Grays Harbor Energy Facility is the winter seasonal rating; the summer seasonal rating for this generating unit is 153 MW and the nameplate rating is 198.9 MW.
Cedar Creek II, LLC ER07-810-000 Grays Harbor Energy Facility 1/1/1960 BPAT Northwest 2008-05 7999 ST1 CC01 291.00 291.00 The “Date Control Transferred” with respect to Grays Harbor Energy LLC’s (“Grays Harbor”) ownership of unit ST1 described in this row of the asset appendix (which is part of the Grays Harbor Energy Facility identified in the EIA data base) is supposed to be the date that it began owning such operating generation assets (i.e., the date that such generation assets began generating test power), however, because this unit of the Grays Harbor Energy Facility began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grays Harbor has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit ST1 of the Grays Harbor Energy Facility is the winter seasonal rating; the summer seasonal rating for this generating unit is 291 MW and the nameplate is 317.10 MW. The current nameplate, summer and winter capacity value for unit ST1 of the Grays Harbor Energy Facility are: 317.10 MW; 291 MW; and 291 MW. These capacity values are different than the values that are currently publicly available on EIA’s Form EIA-860 (e.g., the Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page) because these data do not yet reflect recent revisions that Grays Harbor has made to its Form EIA-860. As a result, the FERC EIA Look Up table may report incorrect values until such time as FERC’s EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN31 0.30 0.30
Cedar Creek II, LLC ER08-1172-000 Grand Ridge Wind Energy Center 1/1/1960 PJM Northeast 2008-10 56941 1 99.00 99.00 The “Date Control Transferred” with respect to Grand Ridge Energy LLC’s (“Grand Ridge I”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Grand Ridge I’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grand Ridge I has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 99 MW.
Cedar Creek II, LLC ER09-430-000 Willow Creek Energy Center 1/1/1960 BPAT Northwest 2009-01 56952 1 72.00 72.00 The “Date Control Transferred” with respect to Willow Creek Energy LLC’s (“Willow Creek”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Willow Creek’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Willow Creek has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix.
Cedar Creek II, LLC ER09-429-000 High Sheldon Wind Farm 1/1/1960 NYIS Northeast 2009-02 56953 1 112.50 112.50 The “Date Control Transferred” with respect to Sheldon Energy LLC’s (“Sheldon”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Sheldon’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Sheldon has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is the same. The current nameplate and seasonal capacity value for Sheldon’s project called High Sheldon Wind Farm is 112.5 MW. These capacity values are different than the values that are currently publicly available on EIA’s Form EIA-860 (e.g., the Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page) because these data do not yet reflect recent revisions that Sheldon has made to its Form EIA-860. As a result, FERC EIA Look Up table may report an incorrect values until such time as FERC’s EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER99-2341-000 Hardee Power Station 1/1/1960 SEC Southeast 1993-01 50949 GEN1 CC01 70.00 70.00 The “Date Control Transferred” with respect to Hardee Power Partners Limited (“Hardee”) ownership of unit GEN1 described in this row of the asset appendix (which is part of the Hardee Power Station identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because each unit of the Hardee Power Station began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Hardee has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN1 of the Hardee Power Station is the summer seasonal rating; the winter seasonal rating for this generating unit is 85 MW.
Cedar Creek II, LLC ER99-2341-000 Hardee Power Station 1/1/1960 SEC Southeast 1993-01 50949 GEN2 CC01 70.00 70.00 The “Date Control Transferred” with respect to Hardee Power Partners Limited (“Hardee”) ownership of unit GEN2 described in this row of the asset appendix (which is part of the Hardee Power Station identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because each unit of the Hardee Power Station began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Hardee has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN2 of the Hardee Power Station is the summer seasonal rating; the winter seasonal rating for this generating unit is 85 MW.
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Boydton Plank Road Cogen Plant 5/1/2000 PJM Northeast 2000-05 54766 GEN34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C1 0.30 0.30
Cedar Creek II, LLC ER99-2341-000 Hardee Power Station 1/1/1960 SEC Southeast 1993-01 50949 GEN4 70.00 70.00 The “Date Control Transferred” with respect to Hardee Power Partners Limited (“Hardee”) ownership of unit GEN4 described in this row of the asset appendix (which is part of the Hardee Power Station identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because each unit of the Hardee Power Station began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Hardee has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN4 of the Hardee Power Station is the summer seasonal rating; the winter seasonal rating for this generating unit is 84 MW.
Cedar Creek II, LLC ER99-2341-000 Hardee Power Station 1/1/1960 SEC Southeast 1993-01 50949 GEN3 CC01 78.00 78.00 The “Date Control Transferred” with respect to Hardee Power Partners Limited (“Hardee”) ownership of unit GEN3 described in this row of the asset appendix (which is part of the Hardee Power Station identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because each unit of the Hardee Power Station began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Hardee has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN3 of the Hardee Power Station is summer seasonal rating; the winter seasonal rating for this generating unit is 85 MW.
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C3 0.30 0.30
Cedar Creek II, LLC ER99-2341-000 Hardee Power Station 1/1/1960 SEC Southeast 2000-05 50949 GEN5 85.00 85.00 The “Date Control Transferred” with respect to Hardee Power Partners Limited (“Hardee”) ownership of unit GEN2 described in this row of the asset appendix (which is part of the Hardee Power Station identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because each unit of the Hardee Power Station began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Hardee has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN5 of the Hardee Power Station is the summer seasonal rating; the winter seasonal rating for this generating unit is 85 MW.
Cedar Creek II, LLC ER06-1334-000 Spindle Hill Energy Center 1/1/1960 PSCO Northwest 2007-05 56445 GEN1 135.00 135.00 The “Date Control Transferred” with respect to Spindle Hill Energy LLC’s (“Spindle Hill”) ownership of unit GEN1 described in this row of the asset appendix (which is part of the Spindle Hill Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Spindle Hill Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Spindle Hill has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN1 of the Spindle Hill Energy Center is the summer seasonal rating; the winter seasonal rating for this generating unit is 155 MW.
Cedar Creek II, LLC ER06-1334-000 Spindle Hill Energy Center 1/1/1960 PSCO Northwest 2007-05 56445 GEN2 135.00 135.00 The “Date Control Transferred” with respect to Spindle Hill Energy LLC’s (“Spindle Hill”) ownership of unit GEN2 described in this row of the asset appendix (which is part of the Spindle Hill Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Spindle Hill Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Spindle Hill has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN2 of the Spindle Hill Energy Center is the summer seasonal rating; the winter seasonal rating for this generating unit is 155 MW.
Cedar Creek II, LLC ER07-277-000 Cannon Falls Energy Center 1/1/1960 MISO Central 2008-04 56241 UNT1 158.00 158.00 The “Date Control Transferred” with respect to Invenergy Cannon Falls LLC’s (“Cannon Falls”) ownership of unit UNT1 described in this row of the asset appendix (which is part of the Cannon Falls Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset(i.e., the date that such generation asset began generating test power), however, because this unit of the Cannon Falls Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Cannon Falls has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit UNT1 of the Cannon Falls Energy Center is the summer seasonal rating; the winter seasonal rating for this generating unit is 181 MW.
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 12/1/2015 TVA Southeast 2015-12 60222 C6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A5 0.30 0.30
Cedar Creek II, LLC ER07-277-000 Cannon Falls Energy Center 1/1/1960 MISO Central 2008-04 56241 UNT2 158.00 158.00 The “Date Control Transferred” with respect to Invenergy Cannon Falls LLC’s (“Cannon Falls”) ownership of unit UNT2 described in this row of the asset appendix (which is part of the Cannon Falls Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Cannon Falls Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Cannon Falls has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit UNT2 of the Cannon Falls Energy Center is the summer seasonal rating; the winter seasonal rating for this generating unit is 181 MW.
Cedar Creek II, LLC ER09-946-000 Beech Ridge Energy LLC 1/1/1960 PJM Northeast 2010-01 57151 GEN1 100.50 100.50 The “Date Control Transferred” with respect to Beech Ridge Energy LLC’s (“Beech Ridge I”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Beech Ridge I’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Beech Ridge I has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 100.5 MW.
Cedar Creek II, LLC ER09-1339-000 Grand Ridge Wind Energy Center 1/1/1960 PJM Northeast 2009-12 56941 2 51.00 51.00 The “Date Control Transferred” with respect to Grand Ridge Energy II LLC’s (“Grand Ridge II”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Grand Ridge II’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grand Ridge II has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 51 MW.
Cedar Creek II, LLC ER09-1340-000 Grand Ridge Wind Energy Center 1/1/1960 PJM Northeast 2009-12 56941 3 49.50 49.50 The “Date Control Transferred” with respect to Grand Ridge Energy III LLC’s (“Grand Ridge III”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Grand Ridge III’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grand Ridge III has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 49.5 MW.
Cedar Creek II, LLC ER09-1341-000 Grand Ridge Battery Projects 1/1/1960 PJM Northeast 2013-12 59957 GIVB 4.50 4.50 The “Date Control Transferred” with respect to Grand Ridge Energy IV LLC’s (“Grand Ridge IV”) ownership and/or control of the storage generation assets described in this row of the asset appendix (which are part of the Grand Ridge Battery Project identified in the EIA data base) is supposed to be the date that it began owning and/or controlling such operating generation assets (i.e., the date that such generation assets began generating test power), however, because such generation assets began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grand Ridge IV has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership and/or control of such generation assets in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported 4.5 MW number for the Grand Ridge Battery Projects portion of Grand Ridge IV’s generation project is the summer rating, the winter rating is 4.5 MW, and the current nameplate value is 4.5 MW. These capacity values for Grand Ridge Battery Projects are different than the values that are currently publicly available on EIA’s Form EIA-860 (e.g., the Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page) because these data do not yet reflect recent revisions that Grand Ridge IV has made to its Form EIA-860. As a result, the FERC EIA Look Up table may report incorrect values until such time as FERC’s EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER09-1341-000 Grand Ridge Wind Energy Center 1/1/1960 PJM Northeast 2009-12 56941 4 10.50 10.50 The “Date Control Transferred” with respect to Grand Ridge Energy IV LLC’s (“Grand Ridge IV”) ownership and/or control of the wind generation assets described in this row of the asset appendix (which are part of the Grand Ridge Wind Energy Center identified in the EIA data base) is supposed to be the date that it began owning and/or controlling such operating generation assets (i.e., the date that such generation assets began generating test power), however, because such generation assets began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Grand Ridge IV has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership and/or control of such generation assets in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. With respect to the 10.5 MW of wind facilities that comprise the Grand Ridge Wind Energy Center, Grand Ridge IV (i) both owns and controls 9 MW of such wind generation facilities and (ii) controls 1.5 MW of such wind generation as the result of contractual arrangements with the party that owns those facilities.
Cedar Creek II, LLC ER09-1342-000 Grand Ridge Energy V 1/1/1960 PJM Northeast 2026-12 80.00 80.00 The generation asset information reported here for Grand Energy V LLC (“Grand Ridge V”) reflects its planned generation project, which is not yet operational, but has been reported in past asset appendices describing Grand Ridge V’s potential generation project, and in developing its analyses of horizontal market power in connection with prior market‐based rate filings because Grand Ridge V may construct a wind generation project that, when completed, could be up to 80 MW (nameplate and seasonal) and located in the PJM geographic market. The ‘Date Control Transferred” with respect to Grand Ridge V’s ownership of its planned generation project is supposed to be the data that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Grand Ridge V’s potential generation project (i.e., the date in which the Grand Ridge V project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Grand Ridge V to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Grand Ridge V’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Grand Ridge V’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs.
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Bristol Plant 10/1/2016 TVA Southeast 2016-10 60222 A6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 37 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 38 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Brunswick Landfill Gas 10/1/2007 PJM Northeast 2007-10 56682 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 39 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 37 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 38 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 39 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 40 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 41 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 42 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 43 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 44 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 45 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 46 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 47 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 48 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Charles City 11/1/2003 PJM Northeast 2003-11 56683 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 37 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 38 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 39 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 40 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 41 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 42 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 43 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 44 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 45 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 46 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 47 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 48 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Chesterfield Landfill Gas 6/1/2004 PJM Northeast 2004-06 56684 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Henrico 9/1/2010 PJM Northeast 2010-09 57356 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 King & Queen 1/1/2008 PJM Northeast 2008-01 56686 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 37 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 38 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 39 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 40 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 41 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 42 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 43 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 44 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 45 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 46 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 47 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 48 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Mountain View 3/1/2003 PJM Northeast 2003-03 56687 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 8/1/2007 CPLE Southeast 2007-08 56688 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New Bern 5/1/2011 CPLE Southeast 2011-05 56688 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 New River 9/1/2013 PJM Northeast 2013-09 59845 E9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Pine Grove 2/1/2008 PJM Northeast 2008-02 56690 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1A 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1B 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1C 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1D 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1E 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1F 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1G 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1H 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1I 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1J 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1K 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1L 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1M 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1N 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 10/1/1995 PJM Northeast 1995-10 56692 1O 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2A 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2B 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2C 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2D 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2E 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2F 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2G 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2H 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2I 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2J 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2K 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2L 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2M 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2N 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2O 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2P 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2Q 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2R 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2S 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2T 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Rockville 1 & 2 6/1/2000 PJM Northeast 2000-06 56692 2U 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 31 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 32 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 33 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 34 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 35 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 36 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Virginia Beach 11/1/2001 PJM Northeast 2001-11 56693 9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2013 CPLE Southeast 2013-09 59688 E9 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E19 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E20 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E21 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E22 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E23 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 9/1/2015 CPLE Southeast 2015-09 59688 E24 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E25 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E26 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E27 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E28 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E29 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wake County LFG Facility 8/1/2019 CPLE Southeast 2019-08 59688 E30 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 1 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 10 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 11 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 12 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 13 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 14 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 15 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 16 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 17 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 18 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 2 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 3 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 4 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 5 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 6 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 7 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 8 0.30 0.30
Cedar Creek II, LLC ER03-0534-000 Wicomico 5/1/2007 PJM Northeast 2007-05 56680 9 0.30 0.30
Cedar Creek II, LLC ER10-1821-000 Goshen Phase II 1/1/1960 PACE Northwest 2010-09 57211 1 124.50 124.50
Cedar Creek II, LLC ER01-1300-000 Whiting Clean Energy 1/1/1960 MISO Central 2002-04 55259 CT1 CC1 181.90 181.90
Cedar Creek II, LLC ER01-1300-000 Whiting Clean Energy 1/1/1960 MISO Central 2002-04 55259 CT2 CC1 181.90 181.90
Cedar Creek II, LLC ER01-1300-000 Whiting Clean Energy 1/1/1960 MISO Central 2002-04 55259 ST1 CC1 231.00 231.00
Cedar Creek II, LLC ER08-1442-000 Flat Ridge Wind Energy LLC 1/1/1960 SWPP Southwest Power Pool 2009-03 56879 1 44.00 44.00
Cedar Creek II, LLC ER09-1655-000 Fowler Ridge Wind Farm LLC 1/1/1960 PJM Northeast 2009-12 56777 FII 49.50 49.50 This 49.5 MW is pseudo-tied into MISO.
Cedar Creek II, LLC ER09-1655-000 Fowler Ridge Wind Farm LLC 1/1/1960 PJM Northeast 2009-12 56777 FII 150.50 150.50
Cedar Creek II, LLC ER08-1323-000 Fowler Ridge Wind Farm LLC 1/1/1960 PJM Northeast 2009-02 56777 FIII 99.00 99.00
Cedar Creek II, LLC ER10-276-000 Rolling Thunder Wind Farm 1/1/1960 SWPP Southwest Power Pool 2009-11 57045 1 25.00 25.00 The Rolling Thunder Facility (EIA Plant Code: 57045) also includes a 0.8 MW battery storage devise. Under Rolling Thunder’s interconnection agreement, the maximum amount of capacity that can be injected onto the transmission system is 25 MW.
Cedar Creek II, LLC ER10-956-000 Vantage Wind Energy LLC 1/1/1960 PSEI Northwest 2010-08 57188 1 90.00 90.00 The “Date Control Transferred” with respect to Vantage Wind Energy LLC’s (“Vantage”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Vantage’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Vantage has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 90 MW.
Cedar Creek II, LLC ER98-2270-000 Archbald Power Station 9/1/1988 PJMF Northeast 1988-09 50279 GEN1 23.20 23.20
Cedar Creek II, LLC ER98-2270-000 Archbald Power Station 2/1/2010 PJMF Northeast 2010-02 50279 GEN5 4.60 4.60
Cedar Creek II, LLC ER98-2270-000 Archbald Power Station 2/1/2010 PJMF Northeast 2010-02 50279 GEN6 4.60 4.60
Cedar Creek II, LLC ER11-2029-000 Cedar Creek II 1/1/1960 PSCO Northwest 2011-03 57210 1 248.30 248.30
Cedar Creek II, LLC ER11-2041-000 Colonie LFGTE Facility NYIS Northeast 2006-02 56324 GEN1 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 Colonie LFGTE Facility NYIS Northeast 2006-02 56324 GEN2 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 Colonie LFGTE Facility NYIS Northeast 2006-02 56324 GEN3 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 Colonie LFGTE Facility NYIS Northeast 2016-06 56324 GEN4 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 DANC LFGTE Facility NYIS Northeast 2008-10 56958 GEN1 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 DANC LFGTE Facility NYIS Northeast 2008-10 56958 GEN2 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 DANC LFGTE Facility NYIS Northeast 2008-10 56958 GEN3 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 DANC LFGTE Facility NYIS Northeast 2012-04 56958 GEN4 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 Fulton LFGTE Facility NYIS Northeast 2010-06 57003 GEN1 1.60 1.60
Cedar Creek II, LLC ER11-2041-000 Fulton LFGTE Facility NYIS Northeast 2010-06 57003 GEN2 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 11/1/2003 NYIS Northeast 2003-11 56250 GEN1 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 11/1/2003 NYIS Northeast 2003-11 56250 GEN2 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 11/1/2003 NYIS Northeast 2003-11 56250 GEN3 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 11/1/2003 NYIS Northeast 2003-11 56250 GEN4 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 5/1/2005 NYIS Northeast 2005-05 56250 GEN5 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 5/1/2005 NYIS Northeast 2005-05 56250 GEN6 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 5/1/2005 NYIS Northeast 2005-05 56250 GEN7 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 11/1/2010 NYIS Northeast 2010-11 56250 GEN8 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 3/1/2013 NYIS Northeast 2013-03 56250 GEN10 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 3/1/2013 NYIS Northeast 2013-03 56250 GEN11 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Ontario LFGTE 3/1/2013 NYIS Northeast 2013-03 56250 GEN9 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 3/1/1996 NYIS Northeast 1996-03 54782 GEN1 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 3/1/1996 NYIS Northeast 1996-03 54782 GEN2 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 3/1/1996 NYIS Northeast 1996-03 54782 GEN3 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1996 NYIS Northeast 1996-08 54782 GEN4 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1996 NYIS Northeast 1996-08 54782 GEN5 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 6/1/1997 NYIS Northeast 1997-06 54782 GEN6 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 6/1/1997 NYIS Northeast 1997-06 54782 GEN7 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GE10 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GE11 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GE12 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GE13 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GE14 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GEN8 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 8/1/1998 NYIS Northeast 1998-08 54782 GEN9 0.80 0.80
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 1/1/2007 NYIS Northeast 2007-01 54782 GE15 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 1/1/2007 NYIS Northeast 2007-01 54782 GE16 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 1/1/2007 NYIS Northeast 2007-01 54782 GE17 1.60 1.60
Cedar Creek II, LLC ER11-2042-000 Seneca Energy 1/1/2007 NYIS Northeast 2007-01 54782 GE18 1.60 1.60
Cedar Creek II, LLC ER11-3872-000 Stony Creek Wind Farm NY 1/1/1960 NYIS Northeast 2013-11 58088 1 93.96 93.96 The “Date Control Transferred” with respect to Stony Creek Energy LLC’s (“Stony Creek”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Stony Creek’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Stony Creek has used the default date of “1960‐ 01‐01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset Table Order 860 submission, which the data base uses to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is the same. The current nameplate and seasonal capacity value for Stony Creek’s project called Stony Creek Wind Farm is 93.96 MW. These capacity values are different than the values that are currently publicly available on EIA’s Form EIA‐860 (e.g., the Final 2020 Form EIA‐860 data set available on EIA’s Form EIA‐860 data page) because these data do not yet reflect recent revisions that Stony Creek has made to its Form EIA‐860. As a result, FERC’s Look Up Table may report an incorrect value until such time as FERC’s EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER11-4044-000 Gratiot County Wind LLC 1/1/1960 MISO Central 2012-05 58677 1 110.40 110.40 The “Date Control Transferred” with respect to Gratiot County Wind LLC’s (“Gratiot I”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Gratiot I’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Gratiot I has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 110.4 MW.
Cedar Creek II, LLC ER12-1400-000 Flat Ridge 2 Wind Energy LLC 1/1/1960 SWPP Southwest Power Pool 2012-10 57787 1 470.40 470.40
Cedar Creek II, LLC ER12-2200-000 Mehoopany Wind Energy LLC 1/1/1960 PJM Northeast 2012-12 57769 1 140.80 140.80
Cedar Creek II, LLC ER14-1317-000 Sunshine Gas Producers 9/1/2014 CISO Southwest 2014-08 58429 1 2.30 2.30 50% owned and operated by DTE
Cedar Creek II, LLC ER14-1317-000 Sunshine Gas Producers 9/1/2014 CISO Southwest 2014-08 58429 2 2.30 2.30 50% owned and operated by DTE
Cedar Creek II, LLC ER14-1317-000 Sunshine Gas Producers 9/1/2014 CISO Southwest 2014-08 58429 3 2.30 2.30 50% owned and operated by DTE
Cedar Creek II, LLC ER14-1317-000 Sunshine Gas Producers 9/1/2014 CISO Southwest 2014-08 58429 4 2.30 2.30 50% owned and operated by DTE
Cedar Creek II, LLC ER14-1317-000 Sunshine Gas Producers 9/1/2014 CISO Southwest 2014-08 58429 5 2.30 2.30 50% owned and operated by DTE
Cedar Creek II, LLC ER14-2187-003 Grand Ridge Battery Projects 1/1/1960 PJM Northeast 2015-03 59957 GRES 31.50 31.50 The “Date Control Transferred” with respect to Grand Ridge Energy Storage LLC’s (“GRES”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because GRES’ generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, GRES has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 31.5 MW.
Cedar Creek II, LLC ER14-2799-001 Beech Ridge Energy Storage 1/1/1960 PJM Northeast 2015-10 60390 BRES 31.50 31.50 The “Date Control Transferred” with respect to Beech Ridge Energy Storage LLC’s (“BRES”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because BRES’ generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, BRES has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for this generating unit is the summer rating; the winter rating for this generating unit is 31.5 MW.
Cedar Creek II, LLC ER15-103-001 Nelson Energy Center 1/1/1960 PJM Northeast 2015-05 55183 ST1 BLK1 125.00 125.00 The “Date Control Transferred” with respect to Invenergy Nelson LLC’s (“Nelson”) ownership of unit ST1 described in this row of the asset appendix (which is part of the Nelson Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Nelson Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Nelson has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit ST1 of the Nelson Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 128 MW.
Cedar Creek II, LLC ER15-103-001 Nelson Energy Center 1/1/1960 PJM Northeast 2015-05 55183 ST2 BLK2 125.00 125.00 The “Date Control Transferred” with respect to Invenergy Nelson LLC’s (“Nelson”) ownership of unit ST2 described in this row of the asset appendix (which is part of the Nelson Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Nelson Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Nelson has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit ST2 of the Nelson Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 128 MW.
Cedar Creek II, LLC ER15-103-001 Nelson Energy Center 1/1/1960 PJM Northeast 2015-05 55183 CT1 BLK1 168.00 168.00 The “Date Control Transferred” with respect to Invenergy Nelson LLC’s (“Nelson”) ownership of unit CT1 described in this row of the asset appendix (which is part of the Nelson Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Nelson Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Nelson has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit CT1 of the Nelson Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 178 MW.
Cedar Creek II, LLC ER15-103-001 Nelson Energy Center 1/1/1960 PJM Northeast 2015-05 55183 CT2 BLK2 168.00 168.00 The “Date Control Transferred” with respect to Invenergy Nelson LLC’s (“Nelson”) ownership of unit CT2 described in this row of the asset appendix (which is part of the Nelson Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Nelson Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Nelson has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit CT2 of the Nelson Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 178 MW.
Cedar Creek II, LLC ER15-1873-001 Buckeye Wind Energy Center 1/1/1960 SWPP Southwest Power Pool 2015-08 58767 1 200.48 200.48 The “Date Control Transferred” with respect to Buckeye Wind Energy LLC’s (“Buckeye”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Buckeye’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Buckeye has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The MW number for used for Buckeye’s generating project is the summer rating; the winter rating for this generating project is 200.48 MW. These values of 200.48 differ slightly from the 200.50 MW amount value that EIA’s Form EIA 860 data base because EIA reports MW values rounded to the nearest tenth.
Cedar Creek II, LLC ER15-2483-001 LRI LFGTE Facility 11/1/2013 PSEI Northwest 2013-11 58688 A 1.50 1.50
Cedar Creek II, LLC ER15-2483-001 LRI LFGTE Facility 11/1/2013 PSEI Northwest 2013-11 58688 B 1.50 1.50
Cedar Creek II, LLC ER15-2483-001 LRI LFGTE Facility 11/1/2013 PSEI Northwest 2013-11 58688 C 1.50 1.50
Cedar Creek II, LLC ER16-2035-000 Black Oak Wind Farm 12/20/2016 MISO Central 2016-12 58692 1 0.00 78.00
Cedar Creek II, LLC ER18-140-001 Lackawanna Energy Center 1/1/1960 PJM Northeast 2018-03 60357 GEN1 454.00 454.00 The “Date Control Transferred” with respect Lackawanna Energy Center LLC’s (“Lackawanna”) ownership of unit GEN 1 described in this row of the asset appendix (which is part of the Lackawanna Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Lackawanna Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Lackawanna has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. In addition to the PJM market listed in this asset appendix, the Lackawanna Energy Center is located in AP South Submarket and 5004/5005 Submarket. The reported MW number for unit GEN 1 of the Lackawanna Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 489 MW and the nameplate rating is 499.5 MW. The current nameplate, summer and winter capacity value unit GEN 1 of the Lackawanna Energy Facility are 499.5 MW; 454 MW and 489 MW. These capacity values are different than the values that are currently publicly available on EIA’s Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page because this data set does not yet reflect recent revisions that Lackawanna has made to its Form EIA-860. As a result, the FERC EIA Look Up table may report incorrect values until such time as the FERC EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER18-140-001 Lackawanna Energy Center 1/1/1960 PJM Northeast 2018-10 60357 GEN2 454.00 454.00 The “Date Control Transferred” with respect Lackawanna Energy Center LLC’s (“Lackawanna”) ownership of unit GEN 2 described in this row of the asset appendix (which is part of the Lackawanna Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Lackawanna Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Lackawanna has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN 2 of the Lackawanna Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 489 MW and the nameplate rating is 499.5 MW. The current nameplate, summer and winter capacity value unit GEN 2 of the Lackawanna Energy Facility are 499.5 MW; 454 MW and 489 MW. These capacity values are different than the values that are currently publicly available on EIA’s Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page because this data set does not yet reflect recent revisions that Lackawanna has made to its Form EIA-860. As a result, the FERC EIA Look Up Table may report incorrect values until such time as the FERCs EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER18-140-001 Lackawanna Energy Center 1/1/1960 PJM Northeast 2018-12 60357 GEN3 454.00 454.00 The “Date Control Transferred” with respect Lackawanna Energy Center LLC’s (“Lackawanna”) ownership of unit GEN 3 described in this row of the asset appendix (which is part of the Lackawanna Energy Center identified in the EIA data base) is supposed to be the date that it began owning such operating generation asset (i.e., the date that such generation asset began generating test power), however, because this unit of the Lackawanna Energy Center began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Lackawanna has used the default date of “1960-01-01” as the “Relationship Start Date” for ownership of such generation asset in the field in its Generation Asset Table Order 860 submission, which the data base used to populate the “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN 3 of the Lackawanna Energy Facility is the summer seasonal rating; the winter seasonal rating for this generating unit is 489 MW and the nameplate rating is 499.5 MW. The current nameplate, summer and winter capacity value unit GEN 3 of the Lackawanna Energy Facility are 499.5 MW; 454 MW and 489 MW. These capacity values are different than the values that are currently publicly available on EIA’s Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page because this data set does not yet reflect recent revisions that Lackawanna has made to its Form EIA-860. As a result, the FERC EIA Look Up Table may report incorrect values until such time as the FERC EIA Lookup Table has been updated with more current EIA data.
Cedar Creek II, LLC ER16-2449-000 Boulder Solar II, LLC 1/27/2017 NEVP Northwest 2017-01 60885 BSII 0.00 50.00
Cedar Creek II, LLC ER17-2088-000 Apple Blossom Wind Farm 11/21/2017 MISO Central 2017-11 58690 APLB1 0.00 100.00
Cedar Creek II, LLC ER18-471-001 States Edge 1 Wind 1/1/1960 SWPP Southwest Power Pool 2025-06 2000.00 2000.00 The generation asset information reported here for States Edge Wind I LLC (“States Edge”) reflects its planned generation project, which is not yet operational, but has been reported in past asset appendices describing States Edge’s potential generation project, and in developing its analyses of horizontal market power in connection with prior market-based rate filings because States Edge may construct a wind generation project that, when completed, could be up to 2000 MW (nameplate and seasonal) and located in the SPP geographic market. The “Date Control Transferred” with respect to States Edge’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date that its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for States Edge’s potential generation project (i.e., the date in which the States Edge project begins generating test power) is not yet known, a temporary default date of 1960-01-01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow States Edge to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In-Service Date” for State Edge’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since States Edge’s generation asset was not yet operating when it submitted the form for a FERC Asset ID, it used an estimated “In-Service Date” for the Operating Month and Year. However, this “In-Service Date” is subject to change based on development schedules and the actual “In-Service Date” when it occurs.
Cedar Creek II, LLC ER18-1197-001 Camilla Solar Energy Project 1/1/1960 SOCO Southeast 61785 CAMSR 171.36 171.36 The “Date Control Transferred” with respect to Camilla Solar Energy LLC’s (“Camilla”) ownership of its generation assets described in this chart is supposed to be the date that it began owning operating generation assets (i.e., the date that its generation assets began generating test power), however, because Camilla’s generation project began test energy operations prior to 10/1/20, as permitted by FERC’s Order No. 860, Camilla has used the default date of “1960-01-01” as the “Relationship Start Date” for its ownership of generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The 171.36 MW for Camilla’s solar generation project differs slightly from the 171.4 MW value in EIA’s Form EIA-860 data base because EIA reports MW values rounded to the nearest tenth.
Cedar Creek II, LLC ER20-2444-000 Millican Solar Energy LLC 2/9/2021 PACW Northwest 63050 GEN1 71.40 71.40 The “Date Control Transferred” with respect to Millican Solar Energy LLC’s ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix.
Cedar Creek II, LLC ER20-2445-000 Prineville Solar Energy LLC 12/1/2020 PACW Northwest 63049 GEN1 46.20 46.20 The “Date Control Transferred” with respect to Prineville Solar Energy LLC’s ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission, which the data base uses to populate “Date Control Transferred” in the Generation asset appendix.
Cedar Creek II, LLC ER21-136-000 Flat Ridge 3 12/31/2021 SWPP Southwest Power Pool 64407 FRW3 0.00 128.00
Cedar Creek II, LLC ER21-258-001 Todd Solar 3/29/2021 PJM Northeast 64690 65004 25.20 25.20 The “Date Control Transferred” with respect to Todd Solar LLC’s (“Todd”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. In addition to the PJM market listed in this chart for Todd’s solar generation project, its project is located in the AP South Submarket, the 5004/5005 Submarket and the PJM East Submarket. The current nameplate and seasonal capacity value for the Todd generation facility is 25.2 MW. This capacity value is different than the value that is currently publicly available on EIA’s Final 2020 Form EIA‐860 data set available on EIA’s Form EIA‐860 data page because this data set does not yet reflect recent revisions that Todd has made to its Form EIA‐860. As a result, the FERC EIA Look Up Table may report incorrect values until such time as the FERCs EIA Lookup Table has been updated with more current EIA data. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Todd’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Todd included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Todd to leave those fields blank or to mark them as N/A, Todd used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER21-628-001 Harry Allen Solar Energy LLC 5/24/2021 NEVP Northwest 63080 GEN1 0.00 100.00
Cedar Creek II, LLC ER21-1251-000 Bighorn Solar 1 4/1/2021 PSCO Northwest 63770 COBH1 240.00 240.00
Cedar Creek II, LLC ER21-1838-000 Orangeville Storage 10/19/2021 NYIS Northeast 64686 65002 24.75 24.75 The “Date Control Transferred” with respect to Orangeville Energy Storage LLC’s (“Orangeville Storage”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The nameplate value and seasonal values of 24.75 MW for the Orangeville Storage project differs slightly from the 24.7 MW value in a recently posted monthly Form EIA-860 covering the month of October 2021, because EIA reports MW values rounded to the nearest tenth. These capacity values are also different than the values that are currently publicly available on EIA’s Final 2020 Form EIA-860 data set available on EIA’s Form EIA-860 data page because this data set does not yet reflect recent revisions that Orangeville Storage has made to its Form EIA-860. While an updated value of 24.7 MW is available in a recently posted monthly Form EIA-860 covering the month of October 2021, the FERC EIA Look Up table may not reflect the updated values. As a result, the FERC EIA Look Up table may report an incorrect nameplate value until such time as FERC’s EIA Lookup Table has been updated with more current EIA data. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Orangeville Storage’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Orangeville Storage included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Orangeville Storage to leave those fields blank or to mark them as N/A, Orangeville Storage used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER21-2715-000 Fairbanks Solar 1/1/1960 MISO Central 2023-09 250.00 250.00 The generation asset information reported here for Fairbank Energy Center LLC (“Fairbanks”) reflects its planned generation project, which is not yet operational, but has been reported in past asset appendices describing Fairbanks’ potential generation project, and in developing its analyses of horizontal market power in connection with prior market‐based rate filings because Fairbanks may construct a solar generation project that, when completed, could be up to 250 MW (nameplate) and located in the MISO geographic market. The “Date Control Transferred” with respect to the Fairbanks ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date that its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Fairbanks’ potential generation project (i.e., the date in which the Fairbanks project begins generating test power) is not yet known, so a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Fairbanks to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Fairbank’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Fairbank’s generation asset was not yet operating when it submitted the form for a FERC Asset ID, it used an estimated “In‐Service Date” for the Operating Month and Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Fairbanks’ generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Fairbanks included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Fairbanks to leave those fields blank or to mark them as N/A, Fairbanks used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER21-2716-000 MISO Central 2023-09 250.00 250.00 The generation asset information reported here reflects a planned generation project that will be owned by Fairbanks Solar Energy Center LLC (“Fairbanks”), which is not yet operational, but has also been reported in connection with Fairbanks Solar Holdings LLC’s (“Fairbanks Holdings”) in past asset appendices describing Fairbanks Holdings’, and in developing its analyses of horizontal market power in connection with prior market-based rate filings, because Fairbanks Holding may possibly exercise a level of control over the Fairbanks solar generation project for a period of time after it begins operations if certain conditions occur pursuant to certain contractual arrangements with a third-party, which could be up to 250 MW (nameplate) and will be located in the MISO geographic market. The “Date Control Transferred” with respect to Fairbanks Holdings’ control of the generation project that will be owned by Fairbanks is supposed to be the date that Fairbanks Holdings’ begins to control pursuant to such contractual arrangements the Fairbanks operating generation project. However, because Fairbanks’ generation project is not yet operational (i.e., the date in which the Fairbanks project begins generating test power has not yet occurred) and Fairbanks Holdings’ does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Fairbanks Holdings with respect to the project, if it occurs, is not yet known. Therefore, Fairbanks Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with the actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Fairbanks Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In-Service Date” for Fairbank’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Fairbank’s generation asset was not yet operating when it submitted the form for a FERC Asset ID, it used an estimated “In-Service Date” for the Operating Month and Year. However, this “In-Service Date” is subject to change based on development schedules and the actual “In-Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While the Fairbanks generation project (which is relevant to Fairbanks Holdings generation market power analysis) has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Fairbanks Holdings’ included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Fairbanks Holdings to leave those fields blank or to mark them as N/A, Fairbanks Holdings used the nameplate rating of the Fairbanks project to populate those fields.
Cedar Creek II, LLC ER22-1999-000 Number Three Wind Project 3/22/2023 NYIS Northeast 2022-10 65522 65013 103.90 103.90 The “Date Control Transferred” with respect to Number Three Wind LLC’s (“Number Three Wind”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Number Three Wind’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Number Three Wind included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Number Three Wind to leave those fields blank or to mark them as N/A, Number Three Wind used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER22-2474-000 Top Hat Wind Energy 1/1/1960 PJM Northeast 2024-12 204.00 204.00 The generation asset information reported here for Top Hat Wind Energy LLC (“Top Hat”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Top Hat may construct a wind generation project that, when completed, could be up to 204 MW (nameplate) and located in the PJM geographic market. The “Date Control Transferred” with respect to Top Hat’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Top Hat’s potential generation project (i.e., the date in which the Top Hat project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Top Hat to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Top Hat’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Top Hat’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Top Hat’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Top Hat included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Top Hat to leave those fields blank or to mark them as N/A, Top Hat used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER22-2475-000 PJM Northeast 2024-12 204.00 204.00 The generation asset information reported here reflects a planned wind generation project that will be owned by Top Hat Wind Energy LLC (“Top Hat”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Top Hat Wind Energy Holdings LLC (“TH Holdings”) relevant market-based rate filings because TH Holdings may possibly exercise a level of control over the Top Hat generation project for a period of time after Top Hat is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project when completed, could be up to 204 MW (nameplate) and located in the PJM geographic market. The “Date Control Transferred” with respect to TH Holdings’ control of the generation project that owned by Top Hat is supposed to be the date that TH Holdings begins to control pursuant to such contractual arrangements the Top Hat operating generation project. However, because TH Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for TH Holdings with respect to the project, if it occurs, is not yet known. Therefore, TH Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow TH Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Top Hat’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Top Hat’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Top Hat’s generation project (which is relevant to TH Holdings’ generation market power analysis) has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that TH Holdings included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow TH Holdings to leave those fields blank or to mark them as N/A, TH Holdings used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER22-2141-000 Sun Mountain Solar 1 7/15/2022 PSCO Northwest 2022-08 200.00 200.00
Cedar Creek II, LLC ER22-2144-001 Invenergy Services LLC 4/20/2023 PJM Northeast 0000-00 60387 GEN3 198.90 198.90 The “Date Control Transferred” with respect to Invenergy Nelson Expansion LLC’s (“NEX”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN 3 of the NEX generation project is the nameplate rating of 198.9 MW; the winter seasonal rating for this generating unit is 179.6 MW and the summer seasonal rating is 157.2 MW. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While NEX’s generation asset has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that NEX included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow NEX to leave those fields blank or to mark them as N/A, NEX used the nameplate rating of its generation asset to populate those fields.
Cedar Creek II, LLC ER22-2144-001 Invenergy Services LLC 4/20/2023 PJM Northeast 0000-00 60387 GEN4 198.90 198.90 The “Date Control Transferred” with respect to Invenergy Nelson Expansion LLC’s (“NEX”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. The reported MW number for unit GEN 4 of the NEX) generation project is the nameplate rating of 198.9 MW; the winter seasonal rating for this generating unit is 179.6 MW and the summer seasonal rating is 157.2 MW. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While NEX’s generation asset has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that NEX included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow NEX to leave those fields blank or to mark them as N/A, NEX used the nameplate rating of its generation asset to populate those fields.
Cedar Creek II, LLC ER22-2519-000 Bellflower Solar 1 9/16/2022 PJM Northeast 2022-09 152.50 152.50
Cedar Creek II, LLC ER22-2283-000 Blackbear Solar 1 8/1/2022 SOCO Southeast 63765 ALBB1 100.00 100.00
Cedar Creek II, LLC ER22-2284-000 Blackbear Solar 1 SOCO Southeast 63765 ALBB1 100.00 100.00
Cedar Creek II, LLC Hokes 1 4/15/2023 PJM Northeast 2022-06 65077 PACT2 20.00 20.00
Cedar Creek II, LLC Hokes 2 4/15/2023 PJM Northeast 2022-07 65082 PACT8 20.00 20.00
Cedar Creek II, LLC ER22-2091-000 Calhoun Solar 11/16/2022 MISO Central 64856 65009 258.80 258.80 The “Date Control Transferred” with respect to Calhoun Solar Energy LLC’s (“Calhoun”) ownership of its generation project in this chart is supposed to be the date it began owning operating generation assets (i.e., the date that its generation assets first began generating test power) and it has used that date as the “Relationship Start Date” for ownership of its generation assets in the field in its Generation Asset table Order 860 submission which the data base uses to populate “Date Control Transferred” in the Generation asset appendix. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Calhoun’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Calhoun included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Calhoun to leave those fields blank or to mark them as N/A, Calhoun used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER23-645-000 Wagon Wheel Wind Project LLC 1/1/1960 SWPP Southwest Power Pool 2025-05 598.40 598.40 The generation asset information reported here for Wagon Wheel Wind Project, LLC (“Wagon Wheel”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Wagon Wheel may construct a wind generation project that, when completed, could be up to 598.4 MW (nameplate and seasonal) and located in the SPP geographic market. The “Date Control Transferred” with respect to Wagon Wheel’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Wagon Wheel’s potential generation project (i.e., the date in which the Wagon Wheel project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Wagon Wheel to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Wagon Wheel’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Wagon Wheel’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Wagon Wheel project consistent with that requirement.
Cedar Creek II, LLC ER23-646-000 SWPP Southwest Power Pool 2025-05 598.40 598.40 The generation asset information reported here reflects a planned wind generation project that will be owned by Wagon Wheel Wind Project, LLC (“Wagon Wheel”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Wagon Wheel Wind Project Holdings LLC (“WW Holdings”) relevant market-based rate filings because WW Holdings may possibly exercise a level of control over the WW generation project for a period of time after Wagon Wheel is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project when completed, could be up to 598.4 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to WW Holdings’ control of the generation project owned by Wagon Wheel is supposed to be the date that WW Holdings begins to control pursuant to such contractual arrangements the Wagon Wheel operating generation project. However, because WW Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for WW Holdings with respect to the project, if it occurs, is not yet known. Therefore, WW Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow WW Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Wagon Wheel’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Wagon Wheel’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015))and the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” for the Wagon Wheel project is consistent with that requirement.
Cedar Creek II, LLC ER23-644-000 Diversion Wind Energy LLC 1/1/1960 SWPP Southwest Power Pool 2024-08 200.60 200.60 The generation asset information reported here for Diversion Wind Energy LLC (“Diversion”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Diversion may construct a wind generation project that, when completed, could be up to 200.6 MW (nameplate and seasonal) and located in the SPP geographic market. The “Date Control Transferred” with respect to Diversion’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Diversion’s potential generation project (i.e., the date in which the Diversion project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Diversion to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Diversion’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Diversion’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Diversion project consistent with that requirement.
Cedar Creek II, LLC ER23-647-000 SWPP Southwest Power Pool 2024-08 200.60 200.60 The generation asset information reported here reflects a planned wind generation project that will be owned by Diversion Wind Energy LLC (“Diversion”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Diversion Wind Energy Holdings LLC (“Diversion Holdings”) relevant market-based rate filings because Diversion Holdings may possibly exercise a level of control over the Diversion generation project for a period of time after Diversion is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project when completed, could be up to 200.6 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Diversion Holdings’ control of the generation project owned by Diversion is supposed to be the date that Diversion Holdings begins to control pursuant to such contractual arrangements the Diversion operating generation project. However, because Diversion Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Diversion Holdings with respect to the project, if it occurs, is not yet known. Therefore, Diversion Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Diversion Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Diversion’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Diversion’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015))and the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” for the Diversion project is consistent with that requirement.
Cedar Creek II, LLC ER23-652-000 Happy Solar 1 2/1/2023 MISO Central 63766 ARHA1 95.00 95.00
Cedar Creek II, LLC ER23-1846-000 Boomtown Solar 1/1/1960 MISO Central 2024-07 150.00 150.00 The generation asset information reported here for Boomtown Solar Energy LLC (“Boomtown”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Boomtown plans to construct a solar generation project that, when completed, could be up to 150 MW (nameplate) and located in the MISO geographic market. The “Date Control Transferred” with respect to Boomtown’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Boomtown’s potential generation project (i.e., the date in which the Boomtown project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Boomtown to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Boomtown’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Boomtown’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)). While Boomtown’s generation project has not been included in any market power study, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” do list a capacity value and rating method, respectively, because these columns are populated using the data that Boomtown included in the “Capacity Rating Adjusted” and “Adj Rating Options” fields its Generation Asset table Order 860 submission. Since the FERC’s data base did not allow Boomtown to leave those fields blank or to mark them as N/A, Boomtown used the nameplate rating of its project to populate those fields.
Cedar Creek II, LLC ER23-2245-000 Pixley Solar 1/1/1960 SWPP Southwest Power Pool 2025-04 189.00 189.00 The generation asset information reported here for Pixley Solar Energy LLC (“Pixley”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Pixley is constructing a solar generation project that, when completed, could be up to 189 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Pixley’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Pixley’s potential generation project (i.e., the date in which the Pixley project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Pixley to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Pixley’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Pixley’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Pixley project consistent with that requirement.
Cedar Creek II, LLC ER23-2244-000 SWPP Southwest Power Pool 2025-04 189.00 189.00 The generation asset information reported here reflects a planned solar generation project that will be owned by Pixley Solar Energy LLC (“Pixley”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Pixley Solar Energy Holdings LLC’s (“Pixley Holdings”) relevant market-based rate filings because Pixley Holdings may possibly exercise a level of control over the Pixley generation project for a period of time after Pixley is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such generation project, when completed, could be up to 189 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Pixley Holdings’ control of the generation project owned by Pixley is supposed to be the date that Pixley Holdings begins to control, pursuant to such contractual arrangements, the Pixley operating generation project). However, because Pixley Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Pixley Holdings with respect to the project, if it occurs, is not yet known. Therefore, Pixley Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs.(Using such a placeholder date was necessary because the FERC’s data base did not allow Pixley Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Pixley’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Pixley’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Pixley project consistent with that requirement.
Cedar Creek II, LLC ER23-2243-000 Lazbuddie Wind 1/1/1960 SWPP Southwest Power Pool 2026-04 265.20 265.20 The generation asset information reported here for Lazbuddie Wind Energy LLC (“Lazbuddie m”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Lazbuddie is constructing a wind generation project that, when completed, could be up to 265.2 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Lazbuddie’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Lazbuddie’s potential generation project (i.e., the date in which the Lazbuddie project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Lazbuddie to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Lazbuddie’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Lazbuddie’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Lazbuddie project consistent with that requirement.
Cedar Creek II, LLC ER23-2242-000 SWPP Southwest Power Pool 2026-04 265.20 265.20 The generation asset information reported here reflects a planned wind generation project that will be owned by Lazbuddie Wind Energy LLC (“Lazbuddie”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Lazbuddie Wind Energy Holdings LLC’s (“Lazbuddie Holdings”) relevant market-based rate filings because Lazbuddie Holdings may possibly exercise a level of control over the Lazbuddie generation project for a period of time after Lazbuddie is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project, when completed, could be up to 265.2 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Lazbuddie Holdings’ control of the generation project owned by Lazbuddie is supposed to be the date that Lazbuddie Holdings begins to control, pursuant to such contractual arrangements, the Lazbuddie operating generation project. However, because Lazbuddie Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Lazbuddie Holdings with respect to the project, if it occurs, is not yet known. Therefore, Lazbuddie Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Lazbuddie Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Lazbuddie’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Lazbuddie’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Lazbuddie project consistent with that requirement.
Cedar Creek II, LLC ER23-2238-000 Flat Ridge 4 Wind 1/1/1960 SWPP Southwest Power Pool 2024-12 135.00 135.00 The generation asset information reported here for Flat Ridge 4 Wind, LLC (“Flat Ridge 4”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Flat Ridge 4 is constructing a wind generation project that, when completed, could be up to 135 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Flat Ridge 4’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Flat Ridge 4’s potential generation project (i.e., the date in which the Flat Ridge 4 project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Flat Ridge 4 to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Flat Ridge 4’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Flat Ridge 4’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Flat Ridge 4 project consistent with that requirement.
Cedar Creek II, LLC ER23-2237-000 SWPP Southwest Power Pool 2024-12 135.00 135.00 The generation asset information reported here reflects a planned wind generation project that will be owned by Flat Ridge 4 Wind, LLC (“Flat Ridge 4”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Flat Ridge 4 Wind Holdings LLC’s (“FR 4 Holdings”) relevant market-based rate filings because FR 4 Holdings may possibly exercise a level of control over the Flat Ridge 4 generation project for a period of time after Flat Ridge 4 is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project, when completed, could be up to 135 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to FR 4 Holdings’ control of the generation project owned by Flat Ridge 4 is supposed to be the date that FR 4 Holdings begins to control, pursuant to such contractual arrangements, the Flat Ridge 4 operating generation project. However, because FR 4 Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for FR 4 Holdings with respect to the project, if it occurs, is not yet known. Therefore, FR 4 Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow FR 4 Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Flat Ridge 4’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Flat Ridge 4’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Flat Ridge 4 project consistent with that requirement.
Cedar Creek II, LLC ER23-2241-000 Flat Ridge 5 Wind 1/1/1960 SWPP Southwest Power Pool 2024-12 153.00 153.00 The generation asset information reported here for Flat Ridge 5 Wind Energy LLC (“Flat Ridge 5”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Flat Ridge 5 is constructing a wind generation project that, when completed, could be up to 153 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Flat Ridge 5’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Flat Ridge 5’s potential generation project (i.e., the date in which the Flat Ridge 5 project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Flat Ridge 5 to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Flat Ridge 5’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Flat Ridge 5’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Flat Ridge 5 project consistent with that requirement.
Cedar Creek II, LLC ER23-2240-000 SWPP Southwest Power Pool 2024-12 153.00 153.00 The generation asset information reported here reflects a planned wind generation project that will be owned by Flat Ridge 5 Wind Energy LLC (“Flat Ridge 5”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Flat Ridge 5 Wind Energy Holdings LLC’s (“FR 5 Holdings”) relevant market-based rate filings because FR 5 Holdings may possibly exercise a level of control over the Flat Ridge 5 generation project for a period of time after Flat Ridge 5 is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such wind generation project, when completed, could be up to 153 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to FR 5 Holdings’ control of the generation project owned by Flat Ridge 5 is supposed to be the date that FR 5 Holdings begins to control, pursuant to such contractual arrangements, the Flat Ridge 5 operating generation project. However, because FR 5 Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for FR 5 Holdings with respect to the project, if it occurs, is not yet known. Therefore, FR 5 Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow FR 5 Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Flat Ridge 5’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Flat Ridge 5’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Flat Ridge 5 project consistent with that requirement.
Cedar Creek II, LLC ER23-2234-000 Algodon Solar 1/1/1960 SWPP Southwest Power Pool 2026-06 150.00 150.00 The generation asset information reported here for Algodon Solar Energy LLC (“Algodon”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Algodon is constructing a solar generation project that, when completed, could be up to 150 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Algodon’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Algodon’s potential generation project (i.e., the date in which the Algodon project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Algodon to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Algodon’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Algodon’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Algodon project consistent with that requirement.
Cedar Creek II, LLC ER23-2233-000 SWPP Southwest Power Pool 2026-06 150.00 150.00 The generation asset information reported here reflects a planned solar generation project that will be owned by Algodon Solar Energy LLC (“Algodon”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Algodon Solar Energy Holdings LLC’s (“Algodon Holdings”) relevant market-based rate filings because Algodon Holdings may possibly exercise a level of control over the Algodon generation project for a period of time after Algodon is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such solar generation project, when completed, could be up to 150 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Algodon Holdings’ control of the generation project owned by Algodon is supposed to be the date that Algodon Holdings begins to control, pursuant to such contractual arrangements, the Algodon operating generation project. However, because Algodon Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Algodon Holdings with respect to the project, if it occurs, is not yet known. Therefore, Algodon Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Algodon Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Algodon’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Algodon’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Algodon project consistent with that requirement.
Cedar Creek II, LLC ER23-2236-000 Chisholm Trail Solar 1/1/1960 SWPP Southwest Power Pool 2025-12 103.50 103.50 The generation asset information reported here for Chisholm Trail Solar Energy LLC (“Chisholm”) reflects its planned generation project, which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with relevant market-based rate filings because Chisholm is constructing a solar generation project that, when completed, could be up to 103.5 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Chisholm’s ownership of its planned generation project is supposed to be the date that it begins owning operating generation assets (i.e., the date its generation assets first begin producing test power). However, because the generation asset is not yet operational, the actual “Date Control Transferred” for Chisholm’s potential generation project (i.e., the date in which the Chisholm project begins generating test power) is not yet known, a temporary default date of 1960‐01‐01 was used as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission for ownership of such generation asset (which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix) until it can be updated with the actual “Date Control Transferred” after that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Chisholm to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Chisholm’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Chisholm’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Chisholm project consistent with that requirement.
Cedar Creek II, LLC ER23-2235-000 SWPP Southwest Power Pool 2025-12 103.50 103.50 The generation asset information reported here reflects a planned solar generation project that will be owned by Chisholm Trail Solar Energy LLC (“Chisholm”), which is not yet operational, but its proposed project capacity has been used in developing analyses of horizontal market power in connection with Chisholm Trail Solar Energy Holdings LLC’s (“Chisholm Holdings”) relevant market-based rate filings because Chisholm Holdings may possibly exercise a level of control over the Chisholm generation project for a period of time after Chisholm is sold to a third-party if certain conditions occur after closing on such sale pursuant to certain contractual arrangements with such a third-party, which such solar generation project, when completed, could be up to 103.5 MW (nameplate) and located in the SPP geographic market. The “Date Control Transferred” with respect to Chisholm Holdings’ control of the generation project owned by Chisholm is supposed to be the date that Chisholm Holdings begins to control, pursuant to such contractual arrangements, the Chisholm operating generation project. However, because Chisholm Holdings does not yet exercise control over the project pursuant to such contractual arrangements, the actual “Date Control Transferred” for Chisholm Holdings with respect to the project, if it occurs, is not yet known. Therefore, Chisholm Holdings used a temporary default date of 1960-01-01 as a placeholder in the “Relationship Start Date” field in its Generation Asset table Order 860 submission, which is the date that the data base uses to populate the “Date Control Transferred” in the Generation asset appendix, until it can be updated with an actual “Date Control Transferred” if and when that date occurs. (Using such a placeholder date was necessary because the FERC’s data base did not allow Chisholm Holdings to leave the “Relationship Start Date” field blank or to mark as N/A.) The asset appendix reflects an “In‐Service Date” for Chisholm’s generation asset that is based on a projected date that was used when it obtained a FERC Asset ID for such asset. The form to obtain a FERC Asset ID required that an Operating Month and Operating Year be provided. Since Chisholm’s generation asset was not yet operating, when it submitted the form for a FERC Asset ID, it used an estimated In-Service Date for the Operating Month and Operating Year. However, this “In‐Service Date” is subject to change based on development schedules and the actual “In‐Service Date” when it occurs. FERC requires that a seller include in the generation asset appendix the MW capacity value and rating method that it used the last time the asset was included in a market power study (see Refinements to Policies and Procedures for Market‐Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities, Order No. 816, 80 Fed. Reg. 67055, at P 266 (Oct. 30, 2015)), and, the columns labeled “Capacity Rating Used In Filing” and “Capacity Rating Method” list a capacity value and rating method, respectively, for the Chisholm project consistent with that requirement.
Cedar Creek II, LLC ER03-0534-000 Amelia 8/1/2001 PJM Northeast 2001-08 56681 40 0.30 0.30
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