No.  BGS Suppliers are not responsible for procuring distribution service.  Distribution service is provided by and at the expense of the EDCs and the EDCs charge retail customers for this service.  Retail customers are responsible for paying the EDCs for distribution services, which are billed under filed tariffs approved by the New Jersey Board of Public Utilities. 

Distribution service is provided by and at the expense of the EDCs and the EDCs charge retail customers for this service.  Retail customers are responsible for paying the EDCs for distribution services, which are billed under filed tariffs approved by the New Jersey Board of Public Utilities.

These "applicable loss expansion factors" are the factors that adjust the hourly load of BGS-CIEP customers metered at the retail meter to the wholesale load level, which then serves as the basis for BGS-CIEP Supplier energy supply responsibility and payment.  The loss expansion factors are further supplemented by application of the marginal loss deration factor.

The 750 kW is a measure of the customer's Peak Load Contribution.

The January 17th update to the monthly data page is the last update to that page prior to the start of the BGS Auctions.  Please note that additional updates have been made to the Additional Data page.  Please see the announcements on the BGS Auction web site (http://www.bgs-auction.com/bgs.press.annc.asp ) for further details.

No, the issue does not affect actual BGS-FP or actual BGS-CIEP load as actual BGS-FP and BGS-CIEP loads are based on the loads of customers actually taking the service at the time.  The issue was only with BGS-FP eligible data prior to June 2011.

The Switching Statistics Report on the Additional Data Tab has an additional 24,944 customers in the C&I total count because it includes Street Lighting Accounts.  The PLA by Rate Class Report does not include Street Lighting Accounts.  Additionally, there will be some difference in total numbers is the Switching Statistics Report as it is pulled near the end of June and the PLA by Rate Class Report is pulled for June 1, 2011.

The capacity obligation of a BGS-FP (CIEP) Supplier is based on the BGS-FP (CIEP) responsibility share, which is the percentage of BGS-FP (CIEP) load won multiplied by the capacity obligation for the BGS-FP (CIEP) group.  This percentage is the percentage represented by a tranche for the EDC times the number of tranches won.

To arrive at capacity obligation for the BGS FP (CIEP) group of an EDC, the Peak Load Allocation posted to the BGS Auction Data Room must (with the exception of JCP&L) be adjusted for the Daily Zonal RPM Scaling Factor and by the Final Zonal RPM Scaling Factor and the Forecast Pool Requirement.  The data for JCP&L is already adjusted for the Daily Zonal RPM Scaling Factor.

The BGS Auction Data Room does not provide historical data on Transmission Enhancement charges.  The PJM web site provides some historical transmission enhancement data showing each EDC's share of the transmission enhancement revenue requirement broken out by transmission service provider within PJM.  Please see the Market Settlements Subcommittee subpage (http://www.pjm.com/committees-and-groups/subcommittees/mss.aspx) and review Schedule 12 of the PJM Open Access Transmission Tariff.

The rates announced by the EDCs prior to the Auctions reflect the Open Access Transmission Tariff (or “OATT”) rates in effect on January 1, 2012 only.  These rates do not include RMR or TECs.  

BGS Suppliers are responsible for paying to PJM all transmission rates associated with serving load including all RMR and TECs in effect at any time.  The actual monthly levels of the RMR and TECs that prevail during the supply period will, for purposes of Section 15.9 of the BGS-CIEP and BGS-FP Supplier Master Agreements, be considered in their entirety to be changes to the rates for Firm Transmission Service. Please review Section 15.9 of the BGS Supplier Master Agreements and the transmission rate announcement posted to the BGS Auction web site on January 19.  The EDCs have and will request that the Board approve recovery of the full amount of RMR payments.  The amount approved the Board, which in the past has been the full amount, will be tracked for the benefit of suppliers and paid to suppliers when subject to a Final FERC Order (as defined in the BGS-FP and BGS-CIEP Supplier Master Agreement) and not subject to refund. 

Please note that for PSE&G, TECs applicable to projects developed by PSE&G and which are applicable to customers in PSE&G’s service territory are included in the rate for Firm Transmission Service.

Also please note that the EDCs have requested and received approval for a variety of RMR and TEC charges and these charges are being tracked for the benefit of suppliers or being paid and will continue to be paid in addition to the BGS price.

RMR is a method of bridging a gap between the deactivation of a generator and the completion of transmission system upgrades needed due to the deactivation.  Under RMR, the generation owner can either elect a Deactivation Avoidable Cost Credit or may file a cost of service rate to recover the entire cost of operating the unit until de-activated.  RMR charges are the same as generation deactivation charges.

Section 15.9 provides for potential recovery of changes in the transmission rates, including RMR.  The transmission rates announced by the EDCs prior to the Auctions reflect the Open Access Transmission Tariff (or “OATT”) rates in effect on January 1, 2012 but do not include RMR charges.  The actual monthly levels of RMR that prevail during the supply period will, for purposes of Section 15.9 of the BGS-CIEP and BGS-FP Supplier Master Agreements, be considered in their entirety to be changes to the rates for Firm Transmission Service. 

Please review Section 15.9 of the BGS Supplier Master Agreements and the transmission rate announcement, which will be posted to the BGS Auction web site on January 20, 2012.  The EDCs have and will request that the Board approve recovery of the full amount of RMR payments.  The amount approved the Board, which in the past has been the full amount, will be tracked for the benefit of suppliers and paid to suppliers when subject to a Final FERC Order (as defined in the BGS-FP and BGS-CIEP Supplier Master Agreement) and not subject to refund.

The results for the 2006 BGS Auctions, including the clearing prices, are available here:

http://www.bgs-auction.com/documents/2006_BGS_Auction_Results.pdf

We thank you for bringing to our attention that the Order from the New Jersey Board of Public Utilities regarding the results of the 2006 BGS Auctions had inadvertently been omitted from the previous results tab of the BGS Auction web site.  This has now been corrected.

“BGS” refers to Basic Generation Service, which is the service that each Electric Distribution Company (i.e., Public Service Electric and Gas Company (“PSE&G”), Jersey Central Power & Light Company (“JCP&L”), Atlantic City Electric Company (“ACE”), and Rockland Electric Company (“RECO”)) provides to its customers.  Each year since 2002, these four New Jersey Electric Distribution Companies have procured electric supply to serve their BGS customers through a statewide auction process held in February.

This web site is to provide information to suppliers that are potential bidders in the statewide auction process.  This web site is not associated with a particular energy company and is not associated with a company called BGS Energy.

The preliminary maximum interests (the “tranche maximums” for each EDC) that you provide with the Part 2 Application are not binding.  In round 1 of the BGS-FP Auction, you will be able to allocate your initial eligibility (your “statewide max”) as you wish across the EDCs subject to the EDC load caps.  In subsequent rounds, you can re-allocate these tranches as you wish, subject to the EDC load caps and subject to the other rules of the Auction.  In particular, if the price for an EDC does not tick down in a round, you cannot reduce (although you may increase) the number of tranches bid on that EDC.  Also, a request to switch from one EDC (i.e., a request to reduce the tranches on one EDC to be able to increase the tranches bid on another EDC) may be denied if, after retaining all withdrawn tranches from that EDC, accepting all reductions from switches would prevent the tranche target for that EDC from being filled.  Tranches from a denied switch are retained at the last price at which they were freely bid.  Please see Section X.C of the BGS-FP Auction Rules. 

Yes, these files include the 10MW of residential load served by JCP&L.

The EDCs no longer update the ancillary services data.  The PJM web site has information concerning ancillary services including black start, market-based regulation, and synchronized reserve data.   Please see

http://www.pjm.com/markets-and-operations/ancillary-services.aspx

Update:

JCP&L provided updated "Ancillary Services" data based on the 10 MW St. Lawrence Load that JCP&L is serving. The data can be found on the Additional Data Page.

The conditions for drawing upon the Pre-Auction Letter of Credit are provided in Paragraph 3.  This states that the EDCs together would present a notice in the form of Annex 1 and that each EDC individually would present Annex 2.  All four EDCs would thus have knowledge and coordinate in drawing upon a Pre-Auction of Credit.  

The BGS Auction Data Room provides historical data on energy from committed supply.  Please see the Additional Data page of the BGS Auction Data Room and scroll down to "Renewable Energy Portfolio Standards".  The EDCs are considering the possibility of providing more data.  The EDCs cannot provide assurances that there will be the same level of renewable energy during the entire BGS-FP supply period.

Update:

The EDCs have updated the Renewable Portfolio Standards: Energy from Committed Supply data on the Additional Data Page to include data from June to December 2011.

The end dates of the contracts that form the EDCs' committed supply are subject to change, renegotiation, as well as action by the New Jersey Board of Public Utilities.  No certainty can be provided to BGS-FP Suppliers that the EDCs' committed supply will or will not remain in place throughout the term of the current BGS-FP period.  The EDCs are considering providing as additional data the current expected date of termination of the contracts that form the EDCs' committed supply.  The BGS Auction Manager will make an announcement in this regard.

The BGS Auction Manager made an announcement regarding transmission rates on January 6, 2012.  Please find it here.

The Additional Data page of the BGS Auction Data Room provides a breakdown between BGS and TPS of the capacity PLC and number of customer accounts for customers in the 500-749 kW range.  Please see the row 'Switching Statistics for BGS-FP Eligible <750 kW' under the BGS-FP matrix.  The EDCs at this time do not at present maintain hourly load for these groups.  Your request for additional data is being considered.

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