Retail Market Subcommittee Retail Market Subcommittee Update to TACUpdate to TAC

Kathy Scott

February 27, 2014 1

2014 WG Leadership Confirmed 2014 WG Leadership Confirmed by RMSby RMSAdvanced Metering Working Group

◦Esther Kent Co- Chair - CenterPoint Energy

◦John Schatz Co-Chair - TXU Energy Texas SET Working Group

◦Diana Rehfeldt Chair - TNMP ◦Kyle Patrick Vice Chair - Reliant/NRG

Texas Data Transport Working Group ◦Isabelle Durham Chair - CenterPoint

Energy◦Gricelda Calzada Vice Chair - AEP Services ◦Monica Jones Vice Chair - Reliant/NRG

February 27, 2014 RMS Update to TAC 2

2014 TF Leadership Confirmed by 2014 TF Leadership Confirmed by RMSRMSMarkeTrak Taskforce

◦Monica Jones Co-Chair - Reliant NRG ◦Carolyn Reed Co-Chair - CenterPoint

Energy◦Sheri Wiegand Co Chair - TXU Energy

Sharyland Transition Taskforce ◦BJ Flowers Co-Chair - Sharyland Utilities◦John Schatz Co-Chair - TXU Energy ◦Kathy Scott Co-Chair - CenterPoint

Energy

February 27, 2014 RMS Update to TAC 3

NPRR Status Report NPRR Status Report NPRR583, Validates CSA Bypass Code in a Move-

Out Request is From Current CSA CR (Vote) ◦ This NPRR requires ERCOT to validate that the CR submitting an

814_24, Move-Out Request containing the Continuous Service Agreement (CSA) bypass code, is also the current CSA CR.

◦ 12/18/13 and 12/19 NPRR583 endorsed by RMS and PRS approved 01/10/14 – NPRR583 RMS Impact Analysis : Between $80k-$90k NPRR583 was unanimously endorsed by RMS with a Priority of

2014 and Rank of 1080.

◦ 01/16/14 – PRS agreed to Table NPRR583 to allow feedback from ERCOT on occurrences and whether the incorrect use of the CSA bypass code violates PUCT Rules or the ERCOT Protocols.

◦ 02/1714 – TX SET Consensus- Withdraw NPRR583 and draft new RMGRR that creates REP Rule 13 denoting that only CSA CRs can send the CSA By-Pass code in the MVO (814_24). This new RMGRR shouldn’t require system changes or cost by ERCOT once approved.

February 27, 2014 RMS Update to TAC 4

SCR Status Report SCR Status Report SCR776, Retail Data Transport Upgrade to

NAESB EDM v2.2 (Vote) This SCR upgrades North American Energy Standards Board

(NAESB) Electronic Delivery Mechanism (EDM) from v1.6 to v2.2, providing ERCOT and Market Participants the ability to support NAESB EDM specified digital signature as well as retail file data identification in compliance with NAESB EDM v2.2.

Strengthens data security and increases efficiency in identifying data for retail file transmissions, such as:

◦ 01/10/14 – SCR776 Impact Analysis Review/Vote: Between $400k and $500k

RMS Unanimously endorsed that PRS “TABLE” SCR776 to allow time for RMS to discuss project’s benefits and implementation options that may reduce cost

◦ 02/05/14 –ERCOT’s update to TDTWG reported a reduction of 100K now $300-$400k, however, TDTWG continues to discuss SCR776 to determine if additional cost savings can be realized.

February 27, 2014 RMS Update to TAC 5

Working Group UpdateWorking Group UpdateTX SET Working Group:

◦ Mass Transition Max. Daily Volume Update: Based upon system designs and the potential for

additional routine daily transactional volumes requiring the same level of attention such as MVIs, MVOs and Switch transactions, the max. daily volume consensus of ERCOT along with AEP, CNP, Nueces, Oncor, Sharyland and TNMP is a maximum of 100,000 unique ESI IDs per day could be transmitted and processed for a Mass Transition or Acquisition Transfer event:

Note: TDSPs stated that their systems haven’t been stressed tested to handle either 75,000 or 100,000 unique ESI IDs per day, but didn’t anticipate any issues with their understanding that ERCOT would initiate switch transactions for100,000 unique ESI IDs per day across all the TDSPs involved in the Mass Transition or Acquisition Transfer event and not 100,000 ESI IDs per each TDSP.

February 27, 2014 RMS Update to TAC 6

Working Group UpdateWorking Group Update

February 27, 2014 RMS Update to TAC 7

February 27, 2014 RMS Update to TAC 8

RETAIL MARKET GUIDE (RMG) APPENDIX F2Timeline for Initiation of a Mass Transition on a Business Day not Prior to a Weekend or ERCOT Holiday

Reference: Section 7.11.1.1.1, Mass Transition Initiation on a Business Day not Prior to a Weekend or ERCOT HolidayCR = Competitive RetailerTDSP = Transmission and/or Distribution Service ProviderPOLR = Provider of Last ResortESI ID = Electric Service Identifier

Day -1 0

Default confirmed and Notification e-mail sent by ERCOT

Daily Market Status Call•867_02, Historical Usage •814_04s, Enrollment Notification Responses, from TDSP to ERCOT •814_14s, Drop Enrollment Requests, from ERCOT to POLR CRs•Customer billing information sent by ERCOT•CBCI file sent by ERCOT

1

Transition Date •Daily market status call•TDSP performs meter reads or estimates for self-selected switch

2 4

Daily Market Status Call•TDSP sends to ERCOT – final 867_03, Monthly or Final Usage, will include out-of-cycle meter read charge •867_04, Initial Meter Read, ERCOT sends to POLR CRs

Monday Tuesday Wednesday Thursday MondayFriday

3

Initial Market Call Mass Transition process:•ESI ID allocation•814_03, Enrollment Notification Request, flow requesting second calendar day•ESI ID lists for POLRs/TDSPs generated

Customer transition should be completed in no more than five calendar days.

February 27, 2014 RMS Update to TAC 9

RETAIL MARKET GUIDE (RMG) APPENDIX F3Timeline for Initiation of a Mass Transition on a Day Before a Weekend or an ERCOT Holiday

Reference: Section 7.11.1.1.2, Mass Transition Initiation on a Business Day Prior to a Weekend or ERCOT HolidayCR = Competitive Retailer ESI ID = Electric Service IdentifierPOLR = Provider of Last ResortTDSP = Transmission and/or Distribution Service Provider

Default confirmed; Notification email sent by ERCOTInitial market call (1800 CPT)

Transition Date •Daily Market Status Call •867_02, Historical Usage •814_04s, Enrollment Notification Responses, from TDSP to ERCOT •814_14s, Drop Enrollment Requests, from ERCOT to POLR CRs•TDSP performs meter reads or estimates for out-of-cycle switch •Customer billing information sent by ERCOT

Daily market status call •TDSP sends to ERCOT - final 867_03, Monthly or Final Usage, will include out-of-cycle meter read charge •867_04, Initial Meter Read•ERCOT sends to POLR CRs

Mass Transition Process:•ESI ID Allocation•814_03, Enrollment Notification Request, flow requesting second day•ESI ID lists for POLRs/TDSPs generated

Day -1 0 1 2 4

Monday Tuesday WednesdaySundayFriday

3

Saturday

Customer transition should be completed in no more than five calendar days.

TDSP’s AMS Install Status TDSP’s AMS Install Status ReportReport: :

AEP – 98.5% complete: ◦1,010,158 as of 01.31.2014

TNMP – 57% complete: ◦ 129,988 as of 01.31.2014

Oncor – 100% complete: ◦3,262,864 as of 12.31.2012

CNP – 100% complete: ◦2,283,012 as of 7.31.2012

Total Number of AMS Meters Installed: 6,686,022

February 27, 2014 RMS Update to TAC 10

Additional Updates:Additional Updates:RMS 2014 Goals

◦ RMS Leadership along with Working Group/Taskforce leaderships will start drafting our 2014 Goals on 3/3/14.

PUCT Staff Training: ◦ RMS Leadership will be reaching out to PUCT Staff and

offering a Retail Market 101 Training for PUCT Staff and other MPs that may be interested.

◦ RMS Leadership will solicit RMS for their participation and requesting RMS input on agenda topics and training material over the next couple of months. Planning will begin in March 2014.

Save the Date: ◦ CenterPoint Energy’s CR Workshop for 2014 planned for

Wednesday, April 30th in Houston.

February 27, 2014 RMS Update to TAC 11

Questions?Questions?

12February 27, 2014 RMS Update to TAC