Commercial Operations Subcommittee (COPS) Update to RMS 6/2/2015

Commercial Operations Subcommittee (COPS)

Update to RMS6/2/2015

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VOTING Item(s) for TAC

LPGRR055, Extend Load Profile Model Calendar Inputs to 2030Proposed Effective Date: June 1, 2015Reason for Revision - AdministrativeExtends the Load Profile Model calendar-related inputs in Appendix E, Profile Model Spreadsheets, from 2020 to 2030. The calendar inputs include calendar variables, daylight savings variables, sunrise/sunset times and holiday variables. Corresponding changes to calendar-related inputs will be made to the Load Profile Models in the MetrixIDR load forecast and backcast system.

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Save the Date – DER Workshop

Distributed Energy Resource (DER) WorkshopJune 18, 2015, 9:30 AM – 3:30 PMERCOT Austin, Room 206WebEx Conference availableA detailed agenda will be posted prior to the meeting

The agenda will include:Discussion of Protocol Section 16.5 (5), which requires a reset of the Distributed Generation (DG) registration threshold if the level of unregistered DG greater than 50kW in a Load Zone reaches 10 MWs. This issue is currently under discussion at CSWG and COPS.Stakeholder input into ERCOT’s outline of the forthcoming white paper on DERs, which was released at the April 9, 2015 ETWG meeting http://www.ercot.com/calendar/2015/4/9/54807-ETWG

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DG Registration ThresholdChange Communication Plan

Background:DG Registration Threshold > 1 MW

– ERCOT Market Participant

– Non-modeled RARFAggregated unregistered DG > 50 kW and <= 1 MW is tracked and reportedProtocol Section 16.5, Registration of a Resource Entity, Paragraph (5)

– If aggregated unregistered DG exceeds 10 MW in any Load Zone, ERCOT shall issue a Market Notice that states a lower DG registration threshold to reduce the total installed capacity of DG greater than 50 kW to no more than 7 MW in any Load Zone

– To become effective 9 months after Market Notice is issued

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CSWG Special Meeting held 5-4-2015Assumptions: Existing Protocol Language

– No Grandfathering for existing DG

– Not a one time event

– The communication will provide the necessary information and not address enforcement

Follow-up items for May 26 CSWG meeting:– ERCOT staff will verify that Customer Billing Contact

Information (CBCI) cannot be used to provide DG Facility Owner contact information

– ERCOT staff will create a straw man communication document for CSWG review

– CSWG will review the DG Resource Webpage on ERCOT.com for possible improvements

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TRIGGER: Unregistered DG reaches 10 MW in any one Load Zone ERCOT: Determine new DG Registration Threshold ERCOT: Issue Market Notice (Includes an email to Authorized

Representatives of all TDSP companies) ERCOT: Meet with appropriate TAC Subcommittees to announce

the new DG Registration Threshold ERCOT: Contact NOIEs and TDSPs of specific DG Facilities

impacted by the new Threshold ERCOT: Work with TDSPs and NOIEs to obtain information needed

to contact the DG Facility Owners ERCOT: Send notice to impacted LSEs’ Authorized Representatives

(This is just a heads up) ERCOT: Contact impacted DG Facility Owners - Include information

like ‘Who is ERCOT’ and step by step instructions on how to become a Market Participant and how to register a DG Resource

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Q1 2015 Settlement Stability Review

First Settlement Stability Report provided by Mandy Bauld and Blake Holt (See Appendix A)

Protocol Section 8.2 (2), Paragraphs (c) and (g) Observations from Q1 2015 report: 8.2(c)(i) Track number of price changes “after the fact”

2015 Q1 2 Intervals 3/25/2015 and 2 Intervals 3/30/2015 8.2(c)(ii) Track number and types of disputes submitted

2014 Total 46, Granted 30 and Denied 162015 Q1 Total 27, Granted 13, Granted w/Exceptions 1, Denied 13

8.2(c)(iii) Response compliance of disputes (timeliness)2014 Total 100%, Final 100% and True-up 100%2015 Q1 Total 100% and True-up 100%

8.2(c)(iv) Other – Variance from Initial Settlement2014 Final Variance 3.18%, True-up Variance 0.34%2015 Q1 Final Variance 3.7%

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Market Information System User Group (MISUG)

SCR775, Indicative LMP DisplayERCOT presented mock-upsLayout and display time period finalizedImplementation target date: 6/26/2015

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Market Information System User Group (MISUG)

External Web Services (EWS) Modifications Workshop IIPreliminary discussions

o Options for providing notificationso Data protection

Next Steps:o ERCOT is working on a demo of a streaming solution that could be

used for smaller sets of high-demand data, e.g., LMPso ERCOT will send out a survey to solicit MP feedback on the best

solution for the Marketo Results to be tabulated and distributed in a future MISUG meetingo Based on feedback, ERCOT will begin defining a revised EWS

interfaceo MISUG will be used as the means for communicating progress

and gathering feedback

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Profiling Working Group (PWG)

Working with TDSPs on an ‘Initial Profile Code Assignments for Temporary Services’ draft LPGRRo Reviewing the possibility of modifying TDSP processes for

handling initial load profile assignments for temporary services for non-residential customers

o Currently, the profile “BUSMEDLF” is used, which has an associated backcast profile of approximately 500 kWh, which has caused credit and customer experience implications

Review of Protocol Section 18, Load Profilingo Ensure content is up-to-date and accurateo Face to face PWG meetings scheduled beginning May 27th

o Target completion by the end of 2015

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The next COPS meeting is scheduled for

July 15, 2015.

Questions?

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Appendix A

Settlement Stability2015 Q1 Update to COPS

Mandy BauldERCOT

COPS04/15/2015

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8.2 ERCOT Performance Monitoring(c) Settlement stability:

(i) Track number of price changes “after-the-fact”; (ii) Track number and types of disputes submitted to ERCOT; (iii) Report on compliance with timeliness of response and disposition of disputes; (iv) Other Settlement metrics; and(v) Availability of Electric Service Identifier (ESI ID) consumption data in conformance with Settlement

timeline;

(g) Uplift: ERCOT shall calculate and post the sum of all charges for all Qualified Scheduling Entities (QSEs) for each month and year-to-date due to each of the following:

(i) The RUC Capacity-Short Charge, as described in Section 5.7.4.1, RUC Capacity-Short Charge; (ii) The RUC Decommitment Charge, as described in Section 5.7.6, RUC Decommitment Charge;(iii) The Load-Allocated Reliability Must Run Amount per QSE, as described in Section 6.6.6.5, RMR Service

Charge;(iv) The Load-Allocated Voltage Support Service Amount per QSE, as described in Section 6.6.7.2, Voltage

Support Charge;(v) The Load-Allocated Black Start Service Amount per QSE, as described in Section 6.6.8.2, Black Start

Capacity Charge;(vi) The Load-Allocated Emergency Energy Amount per QSE, as described in Section 6.6.9.2, Charge for

Emergency Power Increases;(vii) The Load-Allocated Real-Time Revenue Neutrality Amount per QSE, as described in Section 6.6.10, Real-

Time Revenue Neutrality Allocation; and(viii) The total of the ERCOT System Administration Charge

PR 8.2 (2) – Settlement stability

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8.2(c)(i) Track number of price changes “after-the-fact”

Reporting Period: 2015 Q1

Operating Day# of Corrected Prices # of Intervals Affected

DASPP RTSPP RTRMPRORDC Adders

DASPP RTSPP RTRMPRORDC Adders

03/25/2015 0 1196 985 2 0 2 2 2

03/30/2015 0 0 362 0 0 0 2 0

Notes:•Price corrections for OD 3/25/2015 were due to the Tech Refresh Project production cutover.•Price corrections for OD 3/30/2015 were due to an MMS application outage.

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8.2(c)(ii) Track number and types of disputes submitted

YEAR 2014

QUARTER (All)

Row Labels Denied Granted Total

Ancillary Services-RTM 1 1

Congestion Revenue Rights-RTM 1 1

Emergency Operations-RTM 2 2

Energy-DAM 3 3

Energy-RTM 7 21 28

Gene. Res. Base Pt Deviation-RTM 2 4 6

Reliability Unit Commitment-RTM 3 2 5

Grand Total 16 30 46

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8.2(c)(ii) Track number and types of disputes submitted

YEAR 2015

QUARTER Q1

Row Labels Denied GrantedGranted w/Exc.

Grand Total

Congestion Revenue Rights-RTM 1 1

Energy-DAM 1 1

Energy-RTM 2 6 8

Emergency Operations-RTM 9 7 1 17

Grand Total 13 13 1 27

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8.2(c)(iii) Response compliance and disposition of disputes (timeliness)

YEAR 2014

QUARTER (All)

Row Labels FINAL TRUE-UP Total

Ancillary Services-RTM 100% 100%

Congestion Revenue Rights-RTM 100% 100%

Emergency Operations-RTM 100% 100%

Energy-DAM 100% 100%

Energy-RTM 100% 100% 100%

Gene. Res. Base Pt Deviation-RTM 100% 100% 100%

Reliability Unit Commitment-RTM 100% 100% 100%

Grand Total 100% 100% 100%

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8.2(c)(iii) Response compliance and disposition of disputes (timeliness)

YEAR 2015

QUARTER Q1

Row Labels TRUE-UP Grand Total

Congestion Revenue Rights-RTM 100% 100%

Energy-DAM 100% 100%

Energy-RTM 100% 100%

Emergency Operations-RTM 100% 100%

Grand Total 100% 100%

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8.2(c)(iv) Other Settlement metrics

NOTE: ERS Final settlement data is not represented in graph.

Average per year

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NOTE: “Total of Charges” represents the sum of statements that are a net charge to the Market Participant (i.e., the amount due to ERCOT)

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NOTE: “Total of Charges” represents the sum of statements that are a net charge to the Market Participant (i.e., the amount due to ERCOT)

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8.2(c)(v) Availability of ESIID consumption data

March 2015: At month end, settling 6.7M ESIIDs using Advanced Meter data.

March 2015: 98.4% of the load in ERCOT is settled with 15-min interval data (AMS, Competitive IDR, and NOIE IDR).

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8.2(c)(v) Availability of ESIID consumption data

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8.2(g) Uplift

($Millions) $205.90

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PR 8.2 (2) – Settlement stability – potential protocol improvements

Seeking input - Should (g) monitor1)All costs/credits allocated to load, or2)Only the unpreventable load ratio share based charge-types?

Seeking input: 1)Should (c)(iv) remain general so that COPS has the flexibility to change the focus, as needed? (our recommendation)

2)What information should be provided in support of (c)(iv)?3)Other changes?

Documents

Commercial Operations Subcommittee (COPS) Update to RMS 6/2/2015