ARR Reassignment for Retail Load Switching. PJM rules provide that when load switches between LSEs during the planning period, a proportional share of associated ARRs that sink into a given control or load aggregation zone is automatically reassigned to follow that load.30 ARR reassignment occurs daily only if the LSE losing load has ARRs with a net positive economic value to that control zone. An LSE gaining load in the same control zone is allocated a proportional share of positively valued ARRs within the control zone based on the shifted load. ARRs are reassigned to the nearest 0.001 MW and any MW of load may be reassigned multiple times over a planning period. Residual ARRs are also subject to the rules of ARR reassignment. This practice supports competition by ensuring that the offset to congestion follows load, thereby removing a barrier to competition among LSEs and, by ensuring that only ARRs with a positive value are reassigned, preventing an LSE from assigning poor ARR choices to other LSEs. However, when ARRs are self scheduled as FTRs, these underlying self-scheduled FTRs do not follow load that shifts while the ARRs do follow load that shifts, and this may result in lower value of the ARRs for the receiving LSE compared to the total value held by the original ARR holder. There were 64,086 MW of ARRs associated with $338,100 of revenue that were reassigned in the 2013 to 2014 planning period. There were 57,270 MW of ARRs associated with $506,000 of revenue that were reassigned for the 2014 to 2015 planning period. 30 See PJM. “Manual 6: Financial Transmission Rights,” Revision 15 (October 10, 2013), p. 28. Table 13-30 summarizes ARR MW and associated revenue automatically reassigned for network load in each control zone where changes occurred between June 2013 and May 2015. AECO 971 608 $2.5 $3.1 AEP 8,006 2,606 $28.8 $39.2 AP 2,618 2,386 $51.7 $51.0 ATSI 6,792 8,627 $8.7 $70.9 BGE 3,672 3,264 $41.9 $52.7 ComEd 9,664 8,576 $69.9 $95.2 DAY 1,100 794 $2.1 $1.1 DEOK 7,568 6,888 $9.5 $13.9 DLCO 5,248 5,891 $11.1 $10.9 DPL 2,740 2,446 $24.6 $30.5 Dominion 5 20 $0.1 $0.3 EKPC 0 0 0 $0.0 JCPL 1,519 1,354 $4.5 $9.5 Met-Ed 1,043 1,018 $6.8 $11.2 PECO 2,883 2,949 $17.3 $27.1 PENELEC 1,265 1,024 $10.0 $15.4 PPL 3,197 3,958 $12.9 $20.6 PSEG 2,441 1,765 $24.2 $36.8 Pepco 3,134 3,046 $11.6 $16.4 RECO 222 49 $0.0 $0.0 Total 64,086 57,270 $338.1 $506.0 * Through 31-May-2015 Table 13-31 lists the incremental ARR allocation volume for the current and previous planning periods from the 2008 to 2009 planning period through the 2015 to 2016 planning period. 2008/2009 15 890.5 890.5 100% 0 0% 2009/2010 14 530.5 530.5 100% 0 0% 2010/2011 14 531.0 531.0 100% 0 0% 2011/2012 15 595.0 595.0 100% 0 0% 2012/2013 15 687.4 687.4 100% 0 0% 2013/2014 17 1,087.4 1,087.4 100% 0 0% 2014/2015 18 1,447.4 1,447.4 100% 0 0% 2015/2016 18 1,290.5 1,290.5 100% 0 0% Table 13-32 lists the three RTEP upgrade projects that were allocated a total of 678.2 MW of IARRs for the 2015 to 2016 planning period.
Appears in 1 contract
Samples: Financial Transmission and Auction Revenue Rights Agreement
ARR Reassignment for Retail Load Switching. PJM rules provide that when load switches between LSEs during the planning period, a proportional share of associated ARRs that sink into a given control or load aggregation zone is automatically reassigned to follow that load.30 load.23 ARR reassignment occurs daily only if the LSE losing load has ARRs with a net positive economic value to that control zone. An LSE gaining load in the same control zone is allocated a proportional share of positively valued ARRs within the control zone based on the shifted load. ARRs are reassigned to the nearest 0.001 MW and any MW of load may be reassigned multiple times over a planning period. Residual ARRs are also subject to the rules of ARR reassignment. This practice supports competition by ensuring that the offset to congestion follows load, thereby removing a barrier to competition among LSEs and, by ensuring that only ARRs with a positive value are reassigned, preventing an LSE from assigning poor ARR choices to other LSEs. However, when ARRs are self scheduled as FTRs, these underlying self-scheduled FTRs do not follow load that shifts while the ARRs do follow load that shifts, and this may result in lower diminish the value of the ARRs for the receiving LSE compared to the total value held by the original ARR holder. There were 64,086 52,825 MW of ARRs associated with approximately $338,100 498,800 of revenue that were reassigned in the 2012 to 2013 planning period. In the first four months of the 2013 to 2014 planning period. There , there were 57,270 25,157 MW of ARRs associated with approximately $506,000 125,800 of revenue that were reassigned for the 2014 to 2015 planning period. 30 See PJM. “Manual 6: Financial Transmission Rights,” Revision 15 (October 10, 2013), p. 28revenue. Table 13-30 23 summarizes ARR MW and associated revenue automatically reassigned for network load in each control zone where changes occurred between June 2013 2012 and May 2015September 2013. AECO 971 608 581 597 $2.5 3.0 $3.1 2.3 AEP 8,006 2,606 4,656 1,617 $28.8 58.9 $39.2 14.2 AP 2,618 2,386 3,518 876 $51.7 84.3 $51.0 19.0 ATSI 6,792 8,627 5,314 2,437 $8.7 8.3 $70.9 2.6 BGE 3,672 3,264 3,203 2,056 $41.9 37.3 $52.7 14.6 ComEd 9,664 8,576 11,824 5,114 $69.9 170.9 $95.2 21.1 DAY 1,100 794 589 164 $2.1 0.9 $1.1 0.3 DEOK 7,568 6,888 2,979 2,126 $9.5 1.6 $13.9 2.9 DLCO 5,248 5,891 2,708 2,996 $11.1 19.1 $10.9 6.7 DPL 2,740 2,446 1,989 1,071 $24.6 11.5 $30.5 7.4 Dominion 0 5 20 $0.0 $0.1 $0.3 EKPC NA 0 0 0 NA $0.0 JCPL 1,519 1,354 1,373 710 6 $4.5 $9.5 3.3 Met-Ed 1,043 1,018 1,107 393 9 $6.8 3.1 PECO 3,416 494 23 $11.2 PECO 2,883 2,949 4.1 PENELEC 920 408 8 $17.3 4.6 PPL 3,198 1,395 21 $27.1 PENELEC 1,265 1,024 5.3 PSEG 2,313 1,044 17 $10.0 10.1 Pepco 3,073 1,474 21 $15.4 PPL 3,197 3,958 4.2 RECO 67 179 0 $12.9 0.1 Total 52,825 25,157 $20.6 PSEG 2,441 1,765 499.8 $24.2 $36.8 Pepco 3,134 3,046 $11.6 $16.4 RECO 222 49 $0.0 $0.0 Total 64,086 57,270 $338.1 $506.0 125.8 * Through 3130-May-2015 Sep-2013 23 See PJM. “Manual 6: Financial Transmission Rights,” Revision 12 (July 1, 2009), p. 28. Only ARR holders that had their Stage 1A or Stage 1B ARRs prorated are eligible to receive residual ARRs. Residual ARRs are available if additional transmission system capability is added during the planning period after the annual ARR allocation. This additional transmission system capability would not have been accounted for in the initial annual ARR allocation, but it enables the creation of residual ARRs. Residual ARRs are effective on the first day of the month in which the additional transmission system capability is included in FTR auctions and exist until the end of the planning period. For the following planning period, any residual ARRs are available as ARRs in the annual ARR allocation. Stage 1 ARR holders have a priority right to ARRs. Residual ARRs are a separate product from incremental ARRs. Effective August 1, 2012, as ordered by FERC in Docket No. EL12-50-000, in addition to new transmission, residual ARRs are now available for eligible participants when a transmission outage was modeled in the Annual ARR Allocation, but the transmission facility becomes available during the modeled year. These residual ARRs are determined the month before the effective date, are only available on paths prorated in Stage 1 of the Annual ARR Allocation and are allocated automatically to participants. Residual ARRs are effective for single, whole months and cannot be self scheduled. ARR target allocations are based on the clearing prices from FTR obligations in the effective monthly auction, may not exceed zonal Network Services Peak Load or Firm Transmission Reservation Levels and are only available up to the prorated ARR MW capacity as allocated in the Annual ARR Allocation. Table 13-31 lists 24 shows the incremental ARR allocation volume for Residual ARRs automatically allocated to eligible participants, along with the current and previous planning periods target allocations from the 2008 effective month. Jan-13 6,773.0 1,547.2 22.8 $488,251 Feb-13 1,567.4 1,493.7 95.3 $229,856 Mar-13 5,351.2 1,522.7 28.5 $286,193 Apr-13 5,452.1 1,608.9 29.5 $325,662 May-13 6,054.7 1,647.4 27.2 $282,425 Jun-13 10,864.1 1,272.7 11.7 $667,291 Jul-13 10,936.9 1,323.7 12.1 $714,675 Aug-13 9,357.2 767.2 8.2 $236,885 Sep-13 1,855.0 402.9 21.7 $85,884 Total 58,211.6 11,586.4 19.9 $3,317,123 As ARRs are allocated to 2009 planning period through qualifying customers rather than sold, there is no ARR revenue comparable to the 2015 to 2016 planning period. 2008/2009 15 890.5 890.5 100% 0 0% 2009/2010 14 530.5 530.5 100% 0 0% 2010/2011 14 531.0 531.0 100% 0 0% 2011/2012 15 595.0 595.0 100% 0 0% 2012/2013 15 687.4 687.4 100% 0 0% 2013/2014 17 1,087.4 1,087.4 100% 0 0% 2014/2015 18 1,447.4 1,447.4 100% 0 0% 2015/2016 18 1,290.5 1,290.5 100% 0 0% Table 13-32 lists revenue that results from the three RTEP upgrade projects that were allocated a total of 678.2 MW of IARRs for the 2015 to 2016 planning periodFTR auctions.
Appears in 1 contract
Samples: Financial Transmission and Auction Revenue Rights Agreement
ARR Reassignment for Retail Load Switching. PJM rules provide that when load switches between LSEs during the planning period, a proportional share of associated ARRs that sink into a given control or load aggregation zone is automatically reassigned to follow that load.30 load.24 ARR reassignment occurs daily only if the LSE losing load has ARRs with a net positive economic value to that control zone. An LSE gaining load in the same control zone is allocated a proportional share of positively valued ARRs within the control zone based on the shifted load. ARRs are reassigned to the nearest 0.001 MW and any MW of load may be reassigned multiple times over a planning period. Residual ARRs are also subject to the rules of ARR reassignment. This practice supports competition by ensuring that the offset to congestion follows load, thereby removing a barrier to competition among LSEs and, by ensuring that only ARRs with a positive value are reassigned, preventing an LSE from assigning poor ARR choices to other LSEs. However, when ARRs are self scheduled as FTRs, these underlying self-scheduled FTRs do not follow load that shifts while the ARRs do follow load that shifts, and this may result in lower diminish the value of the ARRs for the receiving LSE compared to the total value held by the original ARR holder. There were 64,086 52,825 MW of ARRs associated with approximately $338,100 498,800 of revenue that were reassigned in the 2012 to 2013 to 2014 planning period. There were 57,270 53,988 MW of ARRs associated with approximately $506,000 309,200 of revenue that were reassigned for the first ten months of the 2013 to 2014 to 2015 planning period. 30 See PJM. “Manual 6: Financial Transmission Rights,” Revision 15 (October 10, 2013), p. 28. Table 13-30 22 summarizes ARR MW and associated revenue automatically reassigned for network load in each control zone where changes occurred between June 2013 2012 and May 2015. AECO 971 608 $2.5 $3.1 AEP 8,006 2,606 $28.8 $39.2 AP 2,618 2,386 $51.7 $51.0 ATSI 6,792 8,627 $8.7 $70.9 BGE 3,672 3,264 $41.9 $52.7 ComEd 9,664 8,576 $69.9 $95.2 DAY 1,100 794 $2.1 $1.1 DEOK 7,568 6,888 $9.5 $13.9 DLCO 5,248 5,891 $11.1 $10.9 DPL 2,740 2,446 $24.6 $30.5 Dominion 5 20 $0.1 $0.3 EKPC 0 0 0 $0.0 JCPL 1,519 1,354 $4.5 $9.5 Met-Ed 1,043 1,018 $6.8 $11.2 PECO 2,883 2,949 $17.3 $27.1 PENELEC 1,265 1,024 $10.0 $15.4 PPL 3,197 3,958 $12.9 $20.6 PSEG 2,441 1,765 $24.2 $36.8 Pepco 3,134 3,046 $11.6 $16.4 RECO 222 49 $0.0 $0.0 Total 64,086 57,270 $338.1 $506.0 * Through 31-May-2015 Table 13-31 lists the incremental ARR allocation volume for the current and previous planning periods from the 2008 to 2009 planning period through the 2015 to 2016 planning period. 2008/2009 15 890.5 890.5 100% 0 0% 2009/2010 14 530.5 530.5 100% 0 0% 2010/2011 14 531.0 531.0 100% 0 0% 2011/2012 15 595.0 595.0 100% 0 0% 2012/2013 15 687.4 687.4 100% 0 0% 2013/2014 17 1,087.4 1,087.4 100% 0 0% 2014/2015 18 1,447.4 1,447.4 100% 0 0% 2015/2016 18 1,290.5 1,290.5 100% 0 0% Table 13-32 lists the three RTEP upgrade projects that were allocated a total of 678.2 MW of IARRs for the 2015 to 2016 planning periodMarch 2014.
Appears in 1 contract
Samples: Financial Transmission and Auction Revenue Rights Agreement
ARR Reassignment for Retail Load Switching. Current PJM rules provide that when load switches between LSEs during the planning period, a proportional share of associated ARRs that sink into a given control or load aggregation zone is automatically reassigned to follow that load.30 load.17 ARR reassignment occurs daily only if the LSE losing load has ARRs with a net positive economic value to that control zone. An LSE gaining load in the same control zone is allocated a proportional share of positively valued ARRs within the control zone based on the shifted load. ARRs are reassigned to the nearest 0.001 MW and any MW of load may be reassigned multiple times over a planning period. Residual ARRs are also subject to the rules of ARR reassignment. This practice supports competition by ensuring that the offset to congestion follows load, thereby removing a barrier to competition among LSEs and, by ensuring that only ARRs with a positive value are reassigned, preventing an LSE from assigning poor ARR choices to other LSEs. However, when ARRs are self scheduled as FTRs, these underlying self-self scheduled FTRs do not follow load that shifts while the ARRs do follow 17 See PJM. “Manual 6: Financial Transmission Rights,” Revision 12 (July 1, 2009), p. 28. load that shifts, and this may result in lower diminish the value of the ARRs ARR for the receiving LSE compared to the total value held by the original ARR holder. There were 64,086 41,069 MW of ARRs associated with approximately $338,100 753,500 of revenue that were reassigned in the 2013 first ten months of the 2011 to 2014 2012 planning period. There were 57,270 56,296 MW of ARRs associated with approximately $506,000 1,043,700 of revenue that were reassigned for the 2014 full twelve months of the 2010 to 2015 2011 planning period. 30 See PJM. “Manual 6: Financial Transmission Rights,” Revision Table 12-15 (October 10, 2013), p. 28. Table 13-30 summarizes ARR MW and associated revenue automatically reassigned for network load in each control zone where changes occurred between June 2013 2010 and May 2015March 2012. AECO 971 608 887 436 $2.5 6.0 $3.1 4.7 AEP 8,006 2,606 961 5,919 $28.8 21.4 $39.2 117.9 AP 2,618 2,386 4,992 1,401 $51.7 481.1 $51.0 319.4 ATSI 6,792 8,627 $8.7 $70.9 BGE 3,672 3,264 $41.9 $52.7 ComEd 9,664 8,576 $69.9 $95.2 DAY 1,100 794 $2.1 $1.1 DEOK 7,568 6,888 $9.5 $13.9 DLCO 5,248 5,891 $11.1 $10.9 DPL 2,740 2,446 $24.6 $30.5 Dominion 5 20 $0.1 $0.3 EKPC 0 0 0 2,920 $0.0 JCPL 1,519 1,354 $4.5 13.0 BGE 3,359 2,599 $9.5 Met-Ed 1,043 1,018 50.5 $6.8 45.6 ComEd 3,064 3,215 $11.2 PECO 2,883 2,949 60.2 $17.3 58.0 DAY 193 382 $27.1 PENELEC 1,265 1,024 0.6 $10.0 0.6 DLCO 5,502 8,213 $15.4 PPL 3,197 3,958 25.7 $12.9 10.3 DPL 2,252 3,415 $20.6 PSEG 2,441 1,765 20.4 $24.2 $36.8 Pepco 3,134 3,046 $11.6 $16.4 RECO 222 49 15.2 Dominion 0 1 $0.0 $0.0 JCPL 3,490 1,075 $28.8 $9.9 Met-Ed 3,947 1,178 $51.9 $20.7 PECO 12,284 1,751 $89.2 $21.7 PENELEC 3,745 1,042 $53.5 $21.0 PPL 5,734 3,339 $74.4 $37.6 PSEG 3,416 1,907 $52.8 $30.7 Pepco 2,470 2,277 $27.3 $27.2 RECO 143 57 $0.1 $0.0 Total 64,086 57,270 56,296 41,069 $338.1 1,043.7 $506.0 753.5 * Through 31-May-2015 Table 13-31 lists Mar-12 As ARRs are allocated to qualifying customers rather than sold, there is no ARR revenue comparable to the incremental ARR allocation volume for the current and previous planning periods revenue that results from the 2008 to 2009 planning period through the 2015 to 2016 planning period. 2008/2009 15 890.5 890.5 100% 0 0% 2009/2010 14 530.5 530.5 100% 0 0% 2010/2011 14 531.0 531.0 100% 0 0% 2011/2012 15 595.0 595.0 100% 0 0% 2012/2013 15 687.4 687.4 100% 0 0% 2013/2014 17 1,087.4 1,087.4 100% 0 0% 2014/2015 18 1,447.4 1,447.4 100% 0 0% 2015/2016 18 1,290.5 1,290.5 100% 0 0% Table 13-32 lists the three RTEP upgrade projects that were allocated a total of 678.2 MW of IARRs for the 2015 to 2016 planning periodFTR auctions.
Appears in 1 contract
Samples: Financial Transmission and Auction Revenue Rights Agreement
ARR Reassignment for Retail Load Switching. Current PJM rules provide that when load switches between LSEs during the planning period, a proportional share of associated ARRs that sink into a given control or load aggregation zone is automatically reassigned to follow that load.30 load.56 ARR reassignment occurs daily only if the LSE losing load has ARRs with a net positive economic value to that control zone. An LSE gaining load in the same control zone is allocated a proportional share of positively valued ARRs within the control zone based on the shifted load. ARRs are reassigned to the nearest 0.001 MW and any MW of load may be reassigned multiple times over a planning period. Residual ARRs are also subject to the rules of ARR reassignment. This practice supports competition by ensuring that the offset to congestion follows load, thereby removing a barrier to competition among LSEs and, by ensuring that only ARRs with a positive value are reassigned, preventing an LSE from assigning poor ARR choices to other LSEs. However, when ARRs are self scheduled as FTRs, these underlying self-self scheduled FTRs do not follow load that shifts while the ARRs do follow load that shifts, and this may result in lower diminish the value of the ARRs ARR for the receiving LSE compared to the total value held by the original ARR holder. There were 64,086 MW The MMU recommends that when load switches between LSEs during the planning period, a proportional share of the underlying self scheduled FTRs follow the load in the same manner that ARRs do. ARRs are assigned to firm transmission service customers because these customers pay the costs of the transmission system that enables firm energy delivery. At the time of the FTR Annual Auction, ARR holders have the ability to acquire FTRs by choosing to self schedule in the annual FTR auction. When load switches among LSEs during the planning period, the LSE gaining load is reassigned its proportional share of the ARRs from the LSE losing load. After the Annual FTR Auction has occurred, the LSE gaining load does not have the ability to self schedule FTRs associated with the reassigned ARRs. The self scheduled FTRs are obtained as the direct result of the ARR assignment and should therefore follow the reassignment of ARRs associated with $338,100 of revenue when load switches in order to ensure that were reassigned the new LSE is in the 2013 to 2014 planning periodsame competitive position as the LSE that lost load. There were 57,270 MW of ARRs associated with $506,000 of revenue that were reassigned for the 2014 to 2015 planning period. 30 56 See PJM. “Manual 6: Financial Transmission Rights,” Revision 15 12 (October 10July 1, 20132009), p. 28. Table 1312-30 29 summarizes ARR MW and associated revenue automatically reassigned for network load in each control zone where changes occurred between June 2013 2010 and May 2015December 2011. About 24,531 MW of ARRs associated with $388,700 per MW-day of revenue were automatically reassigned in the first seven months of the 2010 to 2011 planning period. About 56,296 MW of ARRs with $1,043,700 per MW-day of revenue were reassigned for the entire 12-month 2010 to 2011 planning period. AECO 971 608 887 345 $2.5 6.0 $3.1 3.7 AEP 8,006 2,606 961 3,333 $28.8 21.4 $39.2 65.6 AP 2,618 2,386 4,992 961 $51.7 481.1 $51.0 87.1 ATSI 6,792 8,627 $8.7 $70.9 BGE 3,672 3,264 $41.9 $52.7 ComEd 9,664 8,576 $69.9 $95.2 DAY 1,100 794 $2.1 $1.1 DEOK 7,568 6,888 $9.5 $13.9 DLCO 5,248 5,891 $11.1 $10.9 DPL 2,740 2,446 $24.6 $30.5 Dominion 5 20 $0.1 $0.3 EKPC 0 0 0 2,474 $0.0 JCPL 1,519 1,354 $4.5 10.7 BGE 3,359 2,117 $9.5 Met-Ed 1,043 1,018 50.5 $6.8 37.3 ComEd 3,064 2,271 $11.2 PECO 2,883 2,949 60.2 $17.3 40.3 DAY 193 318 $27.1 PENELEC 1,265 1,024 0.6 $10.0 0.5 DLCO 5,502 2,172 $15.4 PPL 3,197 3,958 25.7 $12.9 7.9 DPL 2,252 1,364 $20.6 PSEG 2,441 1,765 20.4 $24.2 $36.8 Pepco 3,134 3,046 $11.6 $16.4 RECO 222 49 12.2 Dominion 0 1 $0.0 $0.0 JCPL 3,490 802 $28.8 $7.3 Met-Ed 3,947 877 $51.9 $15.3 PECO 12,284 1,291 $89.2 $15.5 PENELEC 3,745 803 $53.5 $16.3 PPL 5,734 2,518 $74.4 $28.7 PSEG 3,416 1,235 $52.8 $20.4 Pepco 2,470 1,649 $27.3 $20.0 RECO 143 46 $0.1 $0.0 Total 64,086 57,270 56,296 24,531 $338.1 1,043.7 $506.0 388.7 * Through 31-May-2015 Dec-11 Table 1312-31 30 lists the incremental annual ARR allocation volume by stage and round for the current 2010 to 2011 and previous the 2011 to 2012 planning periods from periods. For the 2008 2011 to 2009 2012 planning period through period, there were 64,160 MW (43.2 percent of total demand) bid in Stage 1A, 22,208 MW (18.4 percent of total demand) bid in Stage 1B and 57,053 MW (38.4 percent of total demand) bid in Stage 2. Of 148,538 MW in total ARR requests 64,160 MW were allocated in Stage 1A and 22,208 MW were allocated in Stage 1B while 16,108 MW were allocated in Stage 2 for a total of 102,476 MW (69.0 percent) allocated. Eligible market participants subsequently converted 46,017 MW of these allocated ARRs into Annual FTRs (44.9 percent of total allocated ARRs), leaving 56,459 MW of ARRs outstanding. For the 2015 2010 to 2016 2011 planning period, there had been 61,793 MW (45.6 percent of total demand) bid in Stage 1A 27,850 MW (20.5 percent of total demand) bid in Stage 1B and 45,971 MW (33.9 percent of total demand) bid in Stage 2. Of 135,614 MW in total ARR requests, 61,793 MW were allocated in Stage 1A and 27,850 MW were allocated in Stage 1B while 12,200 MW were allocated in Stage 2 for a total of 101,842 MW (75.1 percent) allocated. There were 46,017 MW or 54.7 percent of the allocated ARRs converted into FTRs. ARR holders did not relinquish any ARRs for the 2010 to 2011 or the 2011 to 2012 planning period. 2008/2009 15 890.5 890.5 100% 0 0% 2009/2010 14 530.5 530.5 100% 0 0% 2010/2011 14 531.0 531.0 100% 0 0% 2011/2012 15 595.0 595.0 100% 0 0% 2012/2013 15 687.4 687.4 100% 0 0% 2013/2014 17 1,087.4 1,087.4 100% 0 0% 2014/2015 18 1,447.4 1,447.4 100% 0 0% 2015/2016 18 1,290.5 1,290.5 100% 0 0% On June 1, 2011, the American Transmission Systems, Inc. (ATSI) Control Zone was integrated into PJM. Network Service Users and Firm Transmission Customers in the ATSI Control Zone participated in the Annual ARR Allocation and the Annual FTR Auction for the 2011 to 2012 planning period. Table 1312-31 separately lists the ARR volume for the ATSI Control Zone, which is included in the 2011 to 2012 ARR allocation volume in Table 12-30. Table 12-32 lists the three RTEP upgrade projects that were directly allocated a total of 678.2 MW of IARRs FTR volume for the 2015 2011 to 2016 2012 planning periodperiod for the ATSI Control Zone, which is not included in the data in Table 12-30 and Table 12-31. As ARRs are allocated to qualifying customers rather than sold, there is no ARR revenue comparable to the revenue that results from the FTR auctions.
Appears in 1 contract
Samples: Financial Transmission and Auction Revenue Rights Agreement
