Let me make sure I understand this.  Prior to April 2002, the UDCs want their QF costs to be as low as possible, since this will cause the PX credit to be lower and thus the positive CTC higher.  However, beginning April 2002, they pray for just the opposite -- the greater their QF costs, the more they can collect from DA customers to help pay for the QFs.
 
I truly hope I have misunderstood you, else my brain may explode.
 
 

-----Original Message----- 
From: Steffes, James D. 
Sent: Mon 8/13/2001 5:08 PM 
To: Swain, Steve; Mara, Susan 
Cc: 
Subject: One Other Note on Stranded Costs



Steve -- 

As Sue highlights below, when people talk about stranded costs ending no later than 3/31/02, they are only speaking about generation-related stranded costs.  Above market costs for QFs will be "collected" from DA customers for some time into the future.  Wanted to make sure that this was clear.

Jim 

 -----Original Message----- 
From:   Mara, Susan  
Sent:   Monday, August 13, 2001 12:27 PM 
To:     Curry, Wanda; Swain, Steve; Mellencamp, Lisa; Steffes, James D.; Ruffer, Mary Lynne; Tribolet, Michael; Huddleson, Diann

Cc:     Gorny, Vladimir; Bradford, William S.; Kingerski, Harry; Savage, Gordon; Tribolet, Michael 
Subject:        RE: Summary or PX Credit Proposals 

An update from the meeting we had with SCE on August 9:  SCE said that it has TEMPORARILY stopped charging CTC because it doesn't know what to charge for DWR. Meanwhile, it continues to keep track of the dollar flows through the TCBA and the new account set up for DWR.  Once the CPUC decides on the DWR's revenue requirement, SCE expects that it will charge generation-related CTC again.  There is also continuing CTC related to QF contracts that will return (and goes beyond 3/31/02) once QF contracts are above the "market".  SCE is also considering filing a petition with the CPUC to get guidance on all these matters. Once the CPUC rules on SCE"s advice letter approaches, SCE plans to go back and re-bill begining with Jan 18 (it used some different PX credit approaches early on and switched to this approach for bills going out June 4). I didn't ask the question about calculating CTC back to Jan 18.  I guess if the DWR rev req is retroactive and leaves room for CTC, they will bill it.  The other twist I had forgotten about is that they have a one-half cent charge added to the embedded gen rate of 10.27 cents (making it about 10.77 cents) that collects the $400 million that was uncollected while the CPUC played around with a rate design for the three cent surcharge.  The half cent addition is for 12 months.

 -----Original Message----- 
From:   Curry, Wanda  
Sent:   Friday, August 10, 2001 8:51 AM 
To:     Swain, Steve; Mellencamp, Lisa; Steffes, James D.; Ruffer, Mary Lynne; Tribolet, Michael; Huddleson, Diann; Mara, Susan

Cc:     Gorny, Vladimir; Bradford, William S. 
Subject:        Summary or PX Credit Proposals 


I wanted to summarize the conclusions from our meeting on Wednesday, August 8th.  Please let me know if I have misrepresented anything.  

Below is a description of four proposals which may help resolve issues associated with PX credits or mitigate Enron's exposure to PX credits.  Steve Swain has the responsibility for evaluating each proposal, and his goal is to have recommendations for EWS/EES management on August 14th.  

Current Issues: 
1)  The methodology for calculating PX credits after January 18 is undetermined (SCE and PG&E have implemented different methodologies)

2)  Applicability of the 1 cent surcharge to direct access customers (PG&E is passing thru to DA customers, SCE is not) 
3)  Impact to Enron if  FERC implements  retroactive changes to the CAL PX clearing prices from Oct 2, 2000 thru January 18th which result in revised PX credits 

4)  Recoupment of outstanding PX credits against future payments for T&D 
5)  Uncertainty surrounding future tariffs (CTC or other pass through charges), making it difficult to hedge price risk in forward positions

6)  Large uncollected receivables from both PG&E and SCE 


The four proposals are as follows: 

SCE Recommended Approach 
        This approach assumes no PX (or PE) credit effective from January 18, 2001 forward.  Mary Lynne and Diann will work with Steve to quantify the  gross PX receivable (as billed by each utility)  which would  be reversed.   This approach will ensure that only charges for T&D (no    generation/commodity costs, CTC charges, or surcharges for CDWR, including the 1 cent)  will be applicable to Direct Access customers.  

        Enron would request the following: 
        1) Assurances that no surcharges for CDWR will be passed through to EES or EEMC 
        2) SCE will support our historical PX  credit receivable as an "allowable claim" at a minimum and would provide additional credit support if possible.  

        3) PG&E will support Enron's recoupment argument 
        4) Both utilities will immediately reinstate the Cumulative Credit Balances on utility bills and agree to a netting arrangement at the utility parent   level. 

        5) Both utilities agree to not adjust the historical PX credits, if/when an adjustment of historical PX clearing prices is mandated by FERC 

        Other consideration: 
        Ability to hedge price risk in the retail portfolio, without concern re CTC or other surcharge amounts.  


PG&E Recommended Approach 
        This approach assumes the PX calculation methodology effective January 18, 2001 would include an "avoided cost"  component.  This avoided cost  

        component would include, owned generation, QF purchases, actual CDWR purchases for the utility, bilateral purchase contracts, and ISO purchases.        This resulting "avoided cost" would be used in lieu of the PX clearing price in the old PX formula through March, 2002.    If the actual CDWR purchase  costs are not included, then the surcharge (along with the embedded gen costs)  should be included in the calculation.  

        
        Enron would request the following: 
        Same as above 

        Other Consideration: 
        Enron  would continue to be exposed to "price" risk attributable to the actions of the utility at a minimum through March, 2002.  This would hamper     Enron's ability         to hedge the positions in the retail portfolio. 

Hybrid Approach 
        This approach assumes that the PG&E approach is applicable from January 18, 2001 through September 1, 2001 and that the SCE approach is         applicable from September 1st forward.   This approach might be necessary as a compromise for both utilities to provide their support of the proposal. 

        Enron would request the following: 
        Same as SCE and PG&E approach 

        Other considerations: 
        Ability to hedge price risk in the retail portfolio, without concern re CTC or other surcharge amounts.  


Enron Model 
        This approach assumes we continue to support a market based (NP15 and SP15) calculation methodology for the PX credit.   

        Enron would request the following: 
        It is unlikely we would receive any level of cooperation from either PG&E and SCE.   The consensus from legal, regulatory, and EWS commercial is        the probability of getting this approach approved is low.   However, understanding this amount, at a minimum, can be used to help defend the "value"    Enron is foregoing in order to reach agreement with the utilities and CPUC.

        Other considerations: 
        This approach would give Enron the ability to hedge "price" risk, but this is somewhat offset with  incremental credit exposure associated with the     actual collection of the PX credit.


Again, please let me know if this does not clearly represent what we concluded in Wednesday's meeting. 

Thanks, 
Wanda Curry