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The Electric Reliability Council of Texas

Distributed Generation (DG) Protocol References

ERCOT Staff8-20-2015

Distributed Generation, “DG” and “DRG” Protocol References

The following represents a snapshot of many ERCOT Protocols relevant to DERs, as of the publication date (Aug. 20, 2015) of the ERCOT Staff Concept Paper on Distributed Energy Resources in the ERCOT Region. Please note that the ERCOT Protocols are subject to change at any time.

Protocol Section

Protocol Reference and Wording

Summary of Findings:

1. References to Distributed Generation, DG, or DRG references: 7 Protocol sections Do contain (Table of Contents Do Contain) 18 Protocol sections Do Not contain

2. Of the 7 sections containing language, there are approximately 60 references

3. Many references to “Distributed Generation Threshold. Reference itself would not have to change - the change would be to how it is defined in Section 16.5.

4. Most references found in 2 sections: 11: Data Acquisition and Aggregation and 16: Registration and Qualification of Market Participants

5. Potential additions: Adding or changing language in Protocols that do contain references Add new sections on Distributed Generation similar to other new products like Loads in SCED, ERS Weather

Sensitive Loads

Specifics of Protocol references follow.

1 1.3.1.1 Items Considered Protected Information

Source: ERCOT Staff August 2015 Page 1


Protocol Section


Overview

Subject to the exclusions set out in Section 1.3.1.2, Items Not Considered Protected Information, and in Section 3.2.5, Publication of Resource and Load Information, “Protected Information” is information containing or revealing any of the following:

(ee) Status of Non-Modeled Generators and Distributed Generation, including Outages, limitations, or scheduled or metered Resource data. The Protected Information status of this information shall expire 60 days after the applicable Operating Day.

2Definitions

and Acronyms

Definitions

Distributed Generation (DG)

An electrical generating facility located at a Customer’s point of delivery (point of common coupling) ten megawatts (MW) or less and connected at a voltage less than or equal to 60 kilovolts (kV) which may be connected in parallel operation to the utility system.

Distributed Renewable Generation (DRG)

Electric generation with a capacity of not more than 2,000 kW provided by a renewable energy technology that is installed on a retail electric Customer’s side of the meter.

Acronyms

DG Distributed Generation

DRG Distributed Renewable Generation



Protocol Section


3Management Activities for the ERCOT

System

3.14 Contracts for Reliability Resources and Emergency Response Service Resources

ERCOT shall procure Reliability Must-Run (RMR) Service, Black Start Service (BSS) or Emergency Response Service (ERS) through Agreements.

3.14.1 Reliability Must Run

(1) RMR Service is the use by ERCOT, under contracts with Resource Entities, of capacity and energy from Generation Resources that otherwise would not operate and that are necessary to provide voltage support, stability or management of localized transmission constraints under applicable reliability criteria, where market solutions do not exist. This includes service provided by RMR Units and Must-Run Alternative (MRA) Resources.

(b) Before entering into an RMR Agreement, ERCOT shall assess alternatives to the proposed RMR Agreement. ERCOT shall evaluate and present in a written report posted on the Market Information System (MIS) Secure Area the information in items (i) through (v) below. ERCOT is not limited in the number of additional scenarios it chooses to evaluate. The written report shall include an explanation as to why the items below are insufficient, either alone or in combination, to fill the requirement that will be met by the potential RMR Unit. The report shall be posted in the time frame required under paragraph (3) of Section 3.14.1.2, ERCOT Evaluation. The list of alternatives ERCOT must consider includes (as reasonable for each type of reliability concern identified):

(v) Resource alternatives, including capabilities of Distributed Generation (DG), Load Resources, Direct Current Ties (DC Ties), Block Load Transfers (BLTs), etc.

10Metering

10.2 Scope of Metering Responsibilities



Protocol Section


10.2.2 TSP and DSP Metered Entities

(1) Each Transmission Service Provider (TSP) and Distribution Service Provider (DSP) is responsible for supplying ERCOT with meter data associated with:

(a) All Loads using the ERCOT System;

(b) Any All-Inclusive Generation Resource that delivers less than ten MW to the ERCOT System and that is connected directly to the distribution system; a DSP may make some or all such meters ERCOT-Polled Settlement (EPS) compliant and may request that ERCOT poll the meters. Notwithstanding the foregoing sentence, meter data is not required from:

(i) Generation owned by a Non-Opt-In Entity (NOIE) and used for the NOIE’s self-use (not serving Customer Load);

(ii) Distributed Renewable Generation (DRG) with a design capacity less than 50 kW interconnected to a DSP where the owner chooses not to have the out-flow measured in accordance with P.U.C. SUBST. R. 25.213, Metering for Distributed Renewable Generation; and

(iii)Distributed Generation (DG) interconnected to a DSP behind a registered NOIE boundary metering point, not registered as a Generation Resource and with an installed capacity below the DG registration threshold, as determined in Section 16.5, Registration of a Resource Entity, and posted on the Market Information System (MIS) Public Area.

6RTM

Settlement

6.6.3.2 Real-Time Energy Imbalance Payment or Charge at a Load Zone(h) The aggregated generation of its Non-Modeled Generators in the Load Zone.

RTEIAMT q, p = (-1) * {[RTSPP p * [(SSSK q, p * ¼) + (DAEP q, p * ¼) + (RTQQEP q, p * ¼) – (SSSR q, p *



Protocol Section


¼) – (DAES q, p * ¼) – (RTQQES q, p * ¼)]] + [RTSPPEW p * (RTMGNM q, p – RTAML q, p)]}RTMGNM: Real-Time Metered Generation from Non-Modeled generators per QSE per Settlement Point—The total Real-Time energy produced by Non-Modeled Generators represented by QSE q in Load Zone Settlement Point p, for the 15-minute Settlement Interval.

11Data

Acquisition and

Aggregation

Table of Contents: Section 11

11.4.4.2 Load Reduction for Excess PhotoVoltaic and Wind Distributed Renewable Generation 11.4.4.3 Load Reduction for Excess from Other Distributed Generation

11.4.4.2 Load Reduction for Excess PhotoVoltaic and Wind Distributed Renewable Generation

(1) Adjusted Metered Load (AML) for ESI IDs with PhotoVoltaic (PV) generation shall be adjusted as follows:

For ESI IDs with non-IDRs installed, AML shall be reduced for excess generation from ESI IDs with PV generation equal to or lower than the Distributed Generation (DG) registration threshold behind the meter where there is a meter that measures excess energy flow into the ERCOT System in a separate register. Only ESI IDs that have been assigned a PV profile segment as specified in Load Profiling Guide Appendix D, Profile Decision Tree, shall be eligible for this reduction.

Intervals beginning 1100 and ending 1500 Central Prevailing Time (CPT) (spanning (16) 15-minute intervals) shall be reduced by the following amount:

PV_adjust i = kWh_gen / (read_days * 16)

The above variables are defined as follows:Variable Unit Description

PV_adjust i kWh Reduction for PV excess generation for interval i.



Protocol Section


kWh_gen kWh Actual (measured) kWh flowing into the Distribution System (out-flow from the Premise).

read_days days Number of days in meter read period.

(2) AML for ESI IDs with wind generation shall be adjusted as follows:

For ESI IDs with non-IDRs installed, AML shall be reduced for excess generation from ESI IDs with wind generation equal to or lower than the DG registration threshold behind the meter where there is a meter that measures excess energy flow into the ERCOT System in a separate register. Only ESI IDs that have been assigned a wind profile segment as specified in the Load Profiling Guide Appendix D, shall be eligible for this reduction.

Intervals beginning 0800 and ending 2000 CPT (spanning (48) 15-minute intervals) shall be reduced by the following amount:

Wind_adjust = kWh_gen * .65 / (read_days * 48)

All other intervals in the day (the remaining 48 intervals) shall be reduced by the following amount:

Wind_adjust = kWh_gen * .35 / ((read_days * 48) + DST adjust)

Where:Variable Unit Description

wind_adjusti kWh Reduction for wind excess generation for interval i.kWh_gen kWh Actual (measured) kWh flowing into the Distribution System (out-flow

from the Premise).read_days days Number of days in meter read period.DST adjust N/A Daylight Savings Time Adjustment: Spring DST = -4; Fall DST



Protocol Section


= 4.

(3) The excess generation adjustments for ESI IDs, which have PV or wind generation of equal to or lower than the DG registration threshold, as described in Section 16.5, Registration of a Resource Entity, behind the meter and that have an Advanced Metering System (AMS) integrated meter that measures the excess energy flow into the ERCOT System in 15-minute intervals, shall be determined using the actual 15-minute interval data, if available.

11.4.4.3 Load Reduction for Excess from Other Distributed Generation

(1) AML for ESI IDs with DG that is neither PV nor wind shall be adjusted as follows:

For ESI IDs with non-IDRs installed, AML shall be reduced for excess generation from ESI IDs with DG generation of equal to or lower than the DG registration threshold behind the meter where there is a meter that measures excess energy flow into the ERCOT System in a separate register. Only ESI IDs that have been assigned a DG profile segment as specified in Load Profiling Guide Appendix D, Profile Decision Tree, shall be eligible for this reduction.

All intervals in the meter read period shall be reduced by the following amount:

DG _adjust i = kWh_gen / read_ints

The above variables are defined as follows:Variable Unit Description

DG_adjust i kWh Reduction for excess DG for interval i.kWh_gen kWh Actual (measured) kWh flowing into the Distribution System (out-flow

from the Premise).read_ints Intervals Number of 15-minute intervals in the meter read period.



Protocol Section


(2) The energy reduction adjustment for ESI IDs, which have DG equal to or lower than the DG registration threshold behind the meter and have an AMS integrated meter that measures the excess energy flow into the ERCOT System in 15-minute intervals, shall be determined using the actual 15-minute interval data, if available.

16Registration

and Qualification

of MarketParticipants

16.5 Registration of a Resource Entity

(1) A Resource Entity owns or controls an All-Inclusive Resource connected to the ERCOT System. Each Resource Entity operating in the ERCOT Region must register with ERCOT. To become registered as a Resource Entity, an Entity must execute a Standard Form Market Participant Agreement (using the form in Section 22, Attachment A, Standard Form Market Participant Agreement), designate Resource Entity Authorized Representatives, contacts, and a User Security Administrator (USA) (per the Application for Registration as a Resource Entity), and demonstrate to ERCOT’s reasonable satisfaction that it is capable of performing the functions of a Resource Entity under these Protocols. The Resource Entity shall provide Resource Registration data pursuant to Planning Guide Section 6.8.2, Resource Registration Process, for each All-Inclusive Resource through ERCOT registration, except for Distributed Generation (DG) with an installed capacity equal to or lower than the DG registration threshold. A Resource Entity may submit a proposal to register the aggregation of non-wind generators as an Aggregate Generation Resource (AGR) which ERCOT may grant at its sole discretion.

[NPRR588: Replace paragraph (1) above with the following upon system implementation:]

(1) A Resource Entity owns or controls an All-Inclusive Resource connected to the ERCOT System. Each Resource Entity operating in the ERCOT Region must register with ERCOT. To become registered as a Resource Entity, an Entity must execute a Standard Form Market Participant Agreement (using the form in Section 22, Attachment A, Standard Form Market Participant Agreement), designate Resource Entity Authorized Representatives, contacts, and a User Security Administrator (USA) (per the Application



Protocol Section


for Registration as a Resource Entity), and demonstrate to ERCOT’s reasonable satisfaction that it is capable of performing the functions of a Resource Entity under these Protocols. The Resource Entity shall provide Resource Registration data pursuant to Planning Guide Section 6.8.2, Resource Registration Process, for each All-Inclusive Resource through ERCOT registration, except for Distributed Generation (DG) with an installed capacity equal to or lower than the DG registration threshold. A Resource Entity may submit a proposal to register the aggregation of non-Intermittent Renewable Resource (IRR) generators as an Aggregate Generation Resource (AGR) which ERCOT may grant at its sole discretion.

16.5Registration of Resource

Entity

16.5 Registration of a Resource Entity

(5) DG with an installed capacity greater than one MW, the DG registration threshold, must register with ERCOT. ERCOT shall reduce the DG registration threshold as required by these Protocols and post this requirement on the Market Information System (MIS) Public Area. ERCOT shall produce quarterly reports on the total unregistered installed capacity of DG greater than 50 kW below the current threshold, summed by Load Zone. Such quarterly report shall contain the current DG registration threshold. If the total installed capacity of unregistered DG greater than 50 kW exceeds ten MW in any Load Zone, then ERCOT shall issue a Market Notice that states a lower DG registration threshold. Such registration threshold shall be calculated by ERCOT to reduce the total installed capacity of unregistered DG greater than 50 kW to no more than seven MW in any Load Zone. This new DG registration threshold shall become effective nine months after ERCOT has issued the Market Notice and posted the new requirement on the MIS Public Area. Notwithstanding the above, at no time shall ERCOT reduce the DG registration threshold below 50 kW.

(6) Following this Market Notice, ERCOT shall inform the appropriate Technical Advisory Committee (TAC) subcommittee of the change in DG registration requirements at its next meeting. The subcommittee shall analyze the quarterly report, and may take any action it deems appropriate, including submitting a Nodal Protocol Revision Request (NPRR) to alter this Section



Protocol Section


18.Load

Profiling

Table of Contents: Section 18

18.2 Methodology18.2.1 Guidelines for Development of Load Profiles18.2.2 Load Profiles for Non-Interval Metered Loads18.2.2.1 Load Profiles for Non-Interval Metered Loads Without Distributed Generation18.2.2.2 Load Profiles for Non-Interval Metered Loads With Distributed Generation

18.2 Methodology

(1) ERCOT has developed Load Profiles for both non-interval metered Loads and Non-Metered Loads. A Load Profiling Methodology is the fundamental basis on which Load Profiles are created. The implementation of a Load Profiling Methodology may require statistical Sampling, engineering methods, econometric modeling, or other approaches.

(2) The following Load Profiling methods are used:

Type of Load Load Profiling Methodology

Non-interval metered Adjusted Static Models

Non-interval metered with Distribute Generation (DG)

Adjusted Static Models and engineering estimates

Non-metered Engineering estimates



Protocol Section


18.Load

Profiling

18.2.2 Load Profiles for Non-Interval Metered Loads

18.2.2.1 Load Profiles for Non-Interval Metered Loads Without Distributed Generation

Load Profiles for non-interval metered Loads are created using statistical models developed from appropriate Load research sample data. These models are referred to as adjusted static. These model equations relate daily Settlement Interval Load patterns to relevant weather descriptors such as maximum and minimum dry-bulb temperature and humidity. Other daily characteristics such as day-of-the-week and sunrise/sunset times are also employed.

18.2.2.2 Load Profiles for Non-Interval Metered Loads With Distributed Generation

Load Profiles for non-interval metered Loads that utilize DG (e.g., PhotoVoltaic (PV) or wind) will be created using a hybrid approach. At least a portion of the Load Profile will be based on Adjusted Static Models, while engineering estimates and/or generation models may be integrated as well or otherwise utilized.

Seventeen (17) Sections Do Not include any References:

4: Day-Ahead Operations

5: Transmission Security Analysis and Reliability Unit Commitment

6: Adjustment Period and Real-Time Operations

7: Congestion Revenue Rights

8: Performance Monitoring



Protocol Section


9: Settlement and Billing

12: Market Information System

13: Transmission and Distribution Losses

14: State of Texas Renewable Energy Credits Trading Program

15: Customer Registration

17: Market Monitoring and Data Collection

19: Texas Standard Electronic Transaction

20: Alternate Dispute Resolution

21: Revision Request Process

23: Section Left Blank

24: Retail Point to Point Communications

22.Attachment

No references found in Section 22:

A. Standard From Market Participant AgreementB. Standard Form Reliability Must-Run AgreementC. Amendment to Standard Form Market Participant AgreementD. Standard Form Market Participant AgreementE. Notification of Suspension of Operations



Protocol Section


F. Standard Form Synchronous Condenser AgreementG. Standard Form Emergency Response Service AgreementH. Notification of Change of Generation Resource DesignationI. Amendment to Standard Form Black Start AgreementJ. Annual Certification Form to Meet ERCOT Additional Minimum Participation RequirementsK. Declaration of Completion of Generation Resource Weatherization Preparations

ERCOT Fee Schedule

No reference

Table of Contents 2 -17 Distributed Generation (DG) 2-17

2 -17 Distributed Renewable Generation (DRG)

11-1411.4.4.3 Load Reduction for Excess from Other Distributed Generation

18-218.2.2.1 Load Profiles for Non-Interval Metered Loads Without Distributed Generation

18.2.2.2 Load Profiles for Non-Interval Metered Loads With Distributed Generation


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