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AGENDA Meeting No. 20

NPCC Governmental/Regulatory Affairs Advisory Group

The Westin Prince Toronto Hotel 900 York Mills Road

Toronto, Ontario M3B 3H Tel. (416) 444-2511

December 4, 2018 2:00 pm – 5:00 pm

Item Description Est. Time

1. Convene Meeting Introductions Anti-Trust Compliance Guidelines Roster Update

2:00 - 2:15

2. Chair Remarks

3. Regional approach for Distribution level Distributed Energy Resources

Carolyn O’Connor Chair

Guy Zito, AVP – Standards NPCC

2:15 - 2:30

2:30 – 3:00

4. NYSRC Distributed Energy Resources Workshop

Roger Clayton, Chair -

NYSRC Executive Committee

3:00 – 3:30

5. NERC SPIDER Working Group

Michael Lombardi, Manager -System Studies NPCC

3:30 – 4:00

6. DER Modeling Quoc Le, Manager - System Planning and Protection NPCC

4:00 – 4:30

7. NERC Solar Alert II Andrey Oks, Director - Operations Coordination NPCC

4:30 – 5:00

8. Next Meeting(s) All 5:00 – 5:05

Northeast Power Coordinating Council, Inc. (NPCC)

Antitrust Compliance Guidelines It is NPCC’s policy and practice to obey the antitrust laws and to avoid all conduct that unreasonably restrains competition. The antitrust laws make it important that meeting participants avoid discussion of topics that could result in charges of anti-competitive behavior, including: restraint of trade and conspiracies to monopolize, unfair or deceptive business acts or practices, price discrimination, division of markets, allocation of production, imposition of boycotts, exclusive dealing arrangements, and any other activity that unreasonably restrains competition.

It is the responsibility of every NPCC participant and employee who may in any way affect NPCC’s compliance with the antitrust laws to carry out this commitment.

Participants in NPCC activities (including those participating in its committees, task forces and subgroups) should refrain from discussing the following throughout any meeting or during any breaks (including NPCC meetings, conference calls and informal discussions):

• Industry-related topics considered sensitive or market intelligence in nature that are outside of their committee’s scope or assignment, or the published agenda for the meeting; • Their company’s prices for products or services, or prices charged by their competitors; • Costs, discounts, terms of sale, profit margins or anything else that might affect prices; • The resale prices their customers should charge for products they sell them; • Allocating markets, customers, territories or products with their competitors; • Limiting production; • Whether or not to deal with any company; and • Any competitively sensitive information concerning their company or a competitor.

Any decisions or actions by NPCC as a result of such meetings will only be taken in the interest of promoting and maintaining the reliability and adequacy of the bulk power system.

Any NPCC meeting participant or employee who is uncertain about the legal ramifications of a particular course of conduct or who has doubts or concerns about whether NPCC’s antitrust compliance policy is implicated in any situation should call NPCC’s Secretary, Ruta Skucas at 202-530-6428.

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Date: September 4, 2018 To: NPCC Members and Entities

From: Guy V. Zito, NPCC Assistant Vice President – Standards Chair, Regional Standards Committee

Subject: Announcement- Distributed Energy Resource (DER), Bulk Electric System (BES) Impact Reporting, Form and Process

The NPCC Regional Standards Committee (RSC) has developed a voluntary process for reporting and reviewing impacts of distribution utility scale DER BES impacts. The process was developed at the request of the NPCC Board of Directors recognition that increasing amounts and penetration of DER on the BES may have an effect, positive or negative, on BES system performance. Additionally, the process is supportive of the NERC Reliability Issues Steering Committee findings of the reliability risk profile regarding “Changing Resource Mix.” A reporting form has been developed, which is initially posted on the NPCC website. It is located on the NPCC Homepage in the “Latest News” section. NPCC encourages our entities to use this voluntary reporting process to input any previously unknown impacts that DER may have on the BES so these can be reviewed.

The process flowchart NPCC’s RSC has developed will provide an efficient mechanism to ensuring that proper review and consideration is given to impacts and may be found here (DER Impacts). There are many DER related activities currently underway, both within the Region and at NERC, to address some of the known challenges with integration and proliferation of DER. The process is meant to leverage and support existing activities, reduce duplicative efforts, and also identify if analysis of a particular impact is already underway (e.g. NERC’s Inverter Based Task Force) and identify potential opportunities for further analysis.

In the coming months the RSC will be developing accompanying information to further guide and inform the industry of ongoing activities related to DER deployment and update the reporting form and process to effectuate any required further efficiencies.

If you have any questions please contact me.

Respectfully,

Guy V. Zito Chair RCS NPCC Asst. Vice President Standards [email protected] 212-840-1070

https://www.npcc.org/default.aspx

https://www.npcc.org/Standards/commRegStand/Documents/NPCC%20DER%20Proposal%20RCC%20Approved%208-22-2018.pdf

mailto:[email protected]

NYSRC Distributed Energy Resources Workshop Summary

Roger Clayton, NYSRC Chairman

Presentation to NPCC Governmental/Regulatory Affairs Advisory Group

Toronto, Canada. December 4, 2018

NYSRC DER Workshop Agenda – November 7, 2018

Workshop Objective – To raise awareness of possible adverse reliability impacts of widespread DER penetration

1. Introduction

2. Regulatory Status• National• Regional• New York

3. DER Penetration into NYCA (current & future)• Retail (net metered)• Wholesale (REV DSP)• Wholesale (NYISO queue)

4. Technical Considerations• Fundamentals• Operations• Planning

5. Panel Discussion

1/21/2019 NYSRC DER Workshop Summary 2

All presentations available on the NYSRC home page: http://www.nysrc.org/

http://www.nysrc.org/

DER Regulatory Status


FERC• Order 841 – Electric Storage (February 2018)• Staff Report - DER Technical Considerations for the BPS (February 2018)• Technical Conference – DER Technical Considerations for the BPS (April 2018)

IEEE• IEEE Standard 1547-2018 - Interconnection and Interoperability of Distributed Energy Resources with Associated Electric

Power Systems Interfaces• Technical Report - Impact of Inverter Based Generation on BPS Dynamics & Short-Circuit Performance (July 2018)

NERC• Standard PRC-024-2 — Generator Frequency and Voltage Protective Relay Settings (July 2016)• Reliability Guideline – Modeling DER in Dynamic Load Models (December 2016)• Report – Connection Modeling & Reliability Considerations (February 2017)• Reliability Guideline – DER Modeling (September 2017)• Report - 900 MW Fault Induced Solar Photovoltaic Resource Interruption Disturbance (February 2018)• Technical Brief – Data Collection Recommendations (March 2018)• Industry Recommendation – Loss of Solar Resources during Transmission Disturbances due to Inverter Settings (May 2018)• Reliability Guideline – BPS Connected Inverter Based Resource Performance (September 2018)• Working Group - System Planning for Impact of DER (SPIDER WG) (September 2018)

DER Regulatory Status


NPCC• Report on the Impact of DER (March 2016)

• Report on the Effect of Lower System Inertia on Transmission Reliability due to Inverter Based Generation (December 2016)

• UFLS Study on Sensitivity to DER

• On-Going• Development of guidelines & practices to address DER modeling in planning studies

• Examine potential regional approach to DER modeling

• Study potential reliability impacts of DER

DER NYCA Penetration – Retail (Liz Grisaru-NYS DPS)


New York Standardized Interconnection Requirements (SIR) apply to:• New DG facilities sized up to 5 MW AC nameplate aggregated on the customer

side of the PCC;

• New energy storage, stand alone or combined with DG, also limited to 5 MW

• Modifications to an existing facility that affect the interface at the PCC

REV Targets:• 40% reduction in GHG from 1990 levels• 50% renewables <= 2030• 600E12 Btu increase in EE from 1990 levels• 1.5 GW energy storage <= 2025• NY Sun incentive program 3 GW <= 2023



New York State DPS - SIR Interconnection Queue Summary:

http://www3.dps.ny.gov/W/PSCWeb.nsf/96f0fec0b45a3c6485257688006a701a/286d2c179e9a5a8385257fbf003f1f7e/

Number of PV Projects in-service <= August 2018

2,464 2,3773,453

5,102

12,445

23,022

26,757

17,024

11,070

0

5,000

10,000

15,000

20,000

25,000

30,000

2010 2011 2012 2013 2014 2015 2016 2017 2018

PV ONLY - # of Applications Completed - ALL Companies




New York State DPS - SIR Interconnection Queue Summary:


Net Capacity (KW) of PV Projects in Service <= August 2018

PV ONLY - Completed by kW Range (kW) to Date

Company 0-50 50-300 300-1000 1000-2000 2000-5000 Total

National Grid 149,113 49,594 20,154 135,636 - 354,496

Con Edison 140,880 33,711 26,109 6,312 - 207,012

Central Hudson 62,618 6,259 6,094 6,295 - 81,266

Orange and Rockland 48,226 3,437 2,653 16,544 - 70,859

NYSEG 60,512 12,477 8,718 37,502 - 119,208

RGE 11,138 4,307 6,366 22,498 - 44,310

PSEG 299,930 27,241 19,301 13,316 8,000 367,788

Total 772,416 137,025 89,395 238,102 8,000 1,244,938

772,416 ; 62%

137,025 ; 11%

89,395 ; 7%

238,102 ; 19%

8,000 ; 1%

Completed by kW Range (kW)

0-50

50-300

300-1000

1000-2000

2000-5000


DER NYCA Penetration – Wholesale (Paul Haering-Central Hudson)


Interconnected Projects & Queue Size• Queue Coordination is critical as interconnection queues

continues to grow

• Besides PV and Wind, Battery storage resources proposals are becoming significant

DER NYCA Penetration – Wholesale & Retail (NYISO 2018 Gold Book)


Reforming the Energy Vision Programs as of 2018• Distributed Energy Resources (DER)

• Inverter connected solar & wind resources• NYISO 2018 Gold Book nameplate total installed capacity before the meter

• Wind 1739 MW <=2018, ~3,300 MW <=2025 (Queue estimate)• Solar 31 MW <=2018, ~8,900 MW <=2025 (Queue estimate)

• NYISO 2018 Gold Book nameplate total installed capacity behind the meter • Non-solar 213 MW <=2018, ~422 MW <=2025• Solar 1,504 MW <=2018, ~3,313 MW <=2025

DER NYCA Penetration – Wholesale & Retail (Paul Haering-Central Hudson)


Interconnection study lead and process based on three criteria

• Intended Market (Wholesale or Retail)• Interconnection Point (Transmission, Distribution FERC or

non-FERC jurisdicational)• Project Size Intended Market Interconnection Point * Project Size Study Process

Wholesale

NYS Transmission System or Distribution subject to

NYISO’s OATT Interconnection Procedures**

> 5MW NYISO

≤ 5MW NYISO

Distribution not subject to NYISO’s OATT

Interconnection Procedures

> 5MW Utility

≤ 5MW SIR

Retail

NYS Transmission System or Distribution subject to

NYISO’s OATT Interconnection Procedures

> 5MW Utility

≤ 5MW Utility

Distribution not subject to NYISO’s OATT

Interconnection Procedures

> 5MW Utility

≤ 5MW SIR

DER NYCA Penetration – Wholesale (Paul Haering-Central Hudson)


SIR Interconnection process• Coordination of inclusion rules is critical for study work

• Projects are competing for the same interconnection points

• Interconnection procedures are not consistent• SIR and Utility procedures require full deliverability (NYISO

procedure is a minimum interconnect standard)

• Projects may be dependent on upgrades paid for by developers in other interconnection processes

• No ability to share upgrade costs between Interconnection processes

• In many cases the same project may be venue shopping and have applied through both NYISO and Utility Procedures

DER NYCA Penetration – Wholesale (Liz Grisaru-NYS DPS)


Technical Considerations – Fundamentals(John Undrill)


Frequency and Voltage Control in systems with high DER penetration• The availability and prompt delivery of primary frequency response is critical today• The timing of delivery will need to be quicker as the fraction of electronically coupled

equipment increases• The frequency sensitivity and voltage sensitivity of loads are as important as the

characteristics of generation• It will be necessary for electronically coupled generation to contribute primary frequency

response• The effects on frequency control of replacing rotating generation with electronically coupled

DER are system wide• The effects on voltage control of replacing direct connected equipment with electronically

coupled equipment may be mainly local (but not always so)• Proper use of primary response of electronically coupled generation can be expected to

improve quality of frequency and voltage control

Technical Considerations – Operations(Vijaya Ganugula-NYISO)


Technical Considerations – Planning(Pramila Nirbhavane-NYISO)


Major Workshop Conclusions


• The interconnection of DER devices is already significant and continues apace• There are significant challenges to the successful integration of DER into the

electric power system• Resolution of institutional, planning and operational issues for behind the

meter & network DER• Coordination of planning & operations between the DSP & NYISO• Development of appropriate communication requirements, monitoring, supervisory

control & standards• Development of market rules addressing queue inclusion, gaming & curtailment

• Development of appropriate DER simulation tools & planning methods• Validated DER models for individual DER & DER aggregations• Development of integrated transmission & distribution system models• Collection of DER performance data

System Planning Impacts from Distributed Energy Resources Working Group (SPIDERWG)


Agenda Item 5

December 4, 2018

Background• Increasing penetration of DER across North

America

• Aggregate DER impacts to BPS

• Need for focus on DER modeling, system analysis, and BPS impacts

• Need to evolve study approaches and practices to account for aggregate DER

December 4, 2018 2GovReg

SPIDERWG Governance• Working Group reporting to the NERC PC

–Draft Scope: Posted September 2018

– Final Scope: December PC Approval Item

• Leadership:

– Jeff Billinton, CAISO (Chair)

–Bill Quaintance, Duke (Vice Chair)

–Ryan Quint, NERC (Co-Coordinator)

– JP Skeath, NERC (Co-Coordinator)December 4, 2018 3GovReg

SPIDERWG Sub-Groups

• Modeling – Guidelines on data collection and modeling

• Verification – Performance monitoring

• Studies – Guidelines on system planning incorporating aggregated DER

• Coordination – Review and coordination with IEEE Std. 1547-2018


Sub-Group Leads• Modeling

– Irina Green (CAISO)– (Vacant)

• Verification– Michael Lombardi (NPCC)– (Vacant)

• Studies– Jameson Thornton (PG&E)– Peng Wang (IESO)

• Coordination– Kun Zhu (MISO)– Taylor Woodruff (Oncor)


SPIDERWG Schedule

• Kickoff WebEx – October 30, 2018 ✓

• WebEx – November 20, 2018 ✓

• WebEx – December 19, 2018

• Meeting – January 8-9, 2019: Texas RE

• Meeting – April 10-11, 2019: CAISO (tentative)

• Meeting – July 2019: TBD

• Meeting – Q4 2019: TBD


Modeling Deliverables

• Reliability Guideline: DER Data Collection for BPS Planning and System Operations

• Ensure MOD-032 Designees have sufficient processes and procedures for collecting DER data for inclusion in interconnection-wide planning cases; recommendations on dispatch and case setup for various DER scenarios

• Recommended model improvements, model practices, software improvements, and guidance material related to aggregate DER modeling


Verification Deliverables

• Assessment of DER performance and events analysis, distribution system monitoring and data analysis, and recommended model validation and model benchmarking activities.


Studies Deliverables

• Reliability Guideline: System Planning and BPS Reliability Impacts of Aggregated DER


Coordination Deliverables

• Review of, and recommendations related to, the adoption of IEEE Std. 1547-2018; ensure state regulators and policymakers clearly understand BPS reliability perspectives

• Industry workshop or webinar related to aggregate DER impacts to the BPS


Sub-Group Interactions

• Expected interactions:

– Models and how applied in studies

– Tool consistency for models and studies

– How are forecasts incorporating DER

– Model requirements for different types of studies

– Models and model parameters and how they are performing in studies with respect to actual performance


Questions?


February 6, 2018 Page 1

ISO-NE PUBLIC

Inverter Source Requirement Document of ISO New England (ISO-NE) This Source Requirement Document applies to inverters associated with specific types of generation for projects that have applied for interconnection after specific dates. These details will be described in separate document(s). This document was developed with the help of the Massachusetts Technical Standards Review Group and is consistent with the pending revision of the IEEE 1547 Standard for Interconnection and Interoperability of Distributed Resources with Associated Electrical Power Systems Interfaces. All applicable inverter-based applications shall:

be certified per the requirements of UL 1741 SA as a grid support utility interactive inverter

have the voltage and frequency trip settings

have the abnormal performance capabilities (ride-through)

comply with other grid support utility interactive inverter functions statuses These specifications are detailed below and are consistent with the amended IEEE Std 1547a-2014. 1. Certification per UL 1741 SA as grid support utility interactive inverters

In the interim period while IEEE P1547.1 is not yet revised and published, certification of all inverter-based applications:

a. shall be compliant with only those parts of Clause 6 (Response to Area EPS abnormal conditions) of IEEE Std 1547-2018 (2nd ed.)1 that can be certified per the type test requirements of UL 1741 SA (September 2016). IEEE Std 1547-2018 (2nd ed.) in combination with this document replaces other Source Requirements Documents (SRDs), as applicable;

b. may be sufficiently achieved by certifying inverters as grid support utility interactive inverters per the requirements of UL 1741 SA (September 2016) with either CA Rule 21 or Hawai’ian Rule 14H as the SRD. Such inverters are deemed capable of meeting the requirements of this document.

2. Voltage and frequency trip settings for inverter based applications

Applications shall have the voltage and frequency trip points specified in Tables I and II below. 3. Abnormal performance capability (ride-through) requirements for inverter based applications

The inverters shall have the ride-through capability per abnormal performance category II of IEEE Std 1547-2018 (2nd ed.) as quoted in Tables III and IV. The following additional performance requirements shall apply for all inverters:

a. In the Permissive Operation region above 0.5 p.u., inverters shall ride-through in Mandatory Operation mode, and

b. In the Permissive Operation region below 0.5 p.u., inverters shall ride-through in Momentary Cessation mode.

1 In the interim period before IEEE Std 1547-2018 will be published, refer to IEEE P1547 Recirculation 4 Draft 7.3 as a proxy, subject to minor editorial changes.


ISO-NE PUBLIC

Consistent with IEEE Std 1547-2018 (2nd ed.) the following shall apply:

a. DER tripping requirements specified in this SRD shall take precedence over the abnormal performance capability (ride-through) requirements in this section, subject to the following:

1. Where the prescribed trip duration settings for the respective voltage or frequency magnitude are set at least 160 ms or 1% of the prescribed tripping time, whichever is greater, beyond the prescribed ride-through duration, the DER shall comply with the ride-through requirements specified in this section prior to tripping.

2. In all other cases, the ride-through requirements shall apply until 160 ms or 1% of the prescribed tripping time, whichever is greater, prior to the prescribed tripping time.

b. DER ride-through requirements specified in this section shall take precedence over all other requirements within this SRD with the exception of tripping requirements listed in item a. above. Ride-through may be terminated by the detection of an unintentional island. However, false detection of an unintentional island that does not actually exist shall not justify non-compliance with ride-through requirements. Conversely, ride-through requirements specified in this section shall not inhibit the islanding detection performance where a valid unintentional islanding condition exists.

4. Other grid support utility interactive inverter functions statuses

Other functions required by UL 1741 SA shall comply with the requirements specified in Table V. For functions not activated by default, the inverter is compliant if tested to the manufacturers stated capability.

5. Definitions

The following definitions which are consistent with IEEE Std 1547-2018 (2nd ed.) and UL 1741 SA shall apply:

cease to energize: Cessation of active power delivery under steady state and transient conditions and limitation of reactive power exchange. This may lead to momentary cessation or trip. clearing time: The time between the start of an abnormal condition and the DER ceasing to energize the utility’s distribution circuit(s) to which it is connected. It is the sum of the detection time, any adjustable time delay, the operating time plus arcing time for any interposing devices (if used), and the operating time plus arcing time for the interrupting device (used to interconnect the DER with the utility’s distribution circuit).

continuous operation: Exchange of current between the DER and an EPS within prescribed behavior while connected to the utility’s distribution system and while the applicable voltage and the system frequency is within specified parameters.

mandatory operation: Required continuance of active current and reactive current exchange of DER with utility’s distribution system as prescribed, notwithstanding disturbances of the utility’s distribution system voltage or frequency having magnitude and duration severity within defined limits.


ISO-NE PUBLIC

momentary cessation: Temporarily cease to energize the utility’s distribution system while connected to the utility’s distribution system, in response to a disturbance of the applicable voltages or the system frequency, with the capability of immediate restore output of operation when the applicable voltages and the system frequency return to within defined ranges.

permissive operation: operating mode where the DER performs ride-through either in mandatory operation or in momentary cessation, in response to a disturbance of the applicable voltages or the system frequency.


ISO-NE PUBLIC

Table I: Inverters’ Voltage Trip Settings

Shall Trip – IEEE Std 1547-2018 (2nd

ed.) Category II

Shall Trip Function

Required Settings Comparison to IEEE Std 1547-2018 (2

nd ed.)

default settings and ranges of allowable settings for Category II

Voltage (p.u. of nominal voltage)

Clearing Time(s)

Voltage Clearing Time(s)

Within ranges of allowable settings?

OV2 1.20 0.16 Identical Identical Yes

OV1 1.10 2.0 Identical Identical Yes

UV1 0.88 2.0 Higher

(default is 0.70 p.u.) Much shorter

(default is 10 s) Yes

UV2 0.50 1.1 Slightly higher

(default is 0.45 p.u.) Much longer

(default is 0.16 s) Yes

Table II: Inverters’ Frequency Trip Settings

Shall Trip Function

Required Settings Comparison to IEEE Std 1547-2018 (2

nd ed.)

default settings and ranges of allowable settings for Category I, Category II, and Category III

Frequency (Hz)

Clearing Time(s)

Frequency Clearing Time(s)

Within ranges of allowable settings?

OF2 62.0 0.16 Identical Identical Yes

OF1 61.2 300.0 Identical Identical Yes

UF1 58.5 300.0 Identical Identical Yes

UF2 56.5 0.16 Identical Identical Yes

Table III: Inverters’ Voltage Ride-through Capability and Operational Requirements

Voltage Range (p.u.)

Operating Mode/ Response

Minimum Ride-through Time(s) (design criteria)

Maximum Response Time(s) (design criteria)

Comparison to IEEE Std 1547-2018

(2nd

ed.) for Category II

V > 1.20 Cease to Energize N/A 0.16 Identical

1.175 < V ≤ 1.20 Permissive Operation 0.2 N/A Identical

1.15 < V ≤ 1.175 Permissive Operation 0.5 N/A Identical

1.10 < V ≤ 1.15 Permissive Operation 1 N/A Identical

0.88 ≤ V ≤ 1.10 Continuous Operation infinite N/A Identical

0.65 ≤ V < 0.88 Mandatory Operation

Linear slope of 8.7 s/1 p.u. voltage starting at 3 s @ 0.65 p.u.:

𝑇𝑉𝑅𝑇 = 3 s +8.7 s

1 p. u.(𝑉 − 0.65 p.u.)

N/A Identical

0.45 ≤ V < 0.65 Permissive Operation a,b

0.32 N/A See footnotes a & b

0.30 ≤ V < 0.45 Permissive Operation b

0.16 N/A See footnote b

V < 0.30 Cease to Energize N/A 0.16 Identical

The following additional operational requirements shall apply for all inverters:

a. In the Permissive Operation region above 0.5 p.u., inverters shall ride-through in Mandatory Operation mode, and

b. In the Permissive Operation region below 0.5 p.u., inverters shall ride-through in Momentary Cessation mode with a maximum response time of 0.083 seconds.


ISO-NE PUBLIC

Table IV: Inverters’ Frequency Ride-through Capability

Frequency Range (Hz)

Operating Mode Minimum Time(s) (design criteria)

Comparison to IEEE Std 1547-2018

(2nd

ed.) for Category II

f > 62.0 No ride-through requirements apply to this range Identical

61.2 < f ≤ 61.8 Mandatory Operation 299 Identical

58.8 ≤ f ≤ 61.2 Continuous Operation Infinite Identical

57.0 ≤ f < 58.8 Mandatory Operation 299 Identical

f < 57.0 No ride-through requirements apply to this range Identical

Table V: Grid Support Utility Interactive Inverter Functions Status

Function Default Activation State

SPF, Specified Power Factor OFF2

Q(V), Volt-Var Function with Watt or Var Priority OFF

SS, Soft-Start Ramp Rate ON

Default value: 2% of maximum current output per second

FW, Freq-Watt Function OFF

OFF

2 OFF and operating at unity PF. Or set to ON with unity PF.

DER Modeling

NPCC Governmental and Regulatory Affairs Advisory GroupDecember 4, 2018 Meeting

Toronto, Ontario

Quoc LeManager, System Planning & Protection

Studies That Require DER Models

• Steady-state power flow studies

• Short-circuit studies

• Dynamic disturbance ride-through studies

• Dynamic transient stability studies

2

Steady-State Studies

• Modeling of DER in these studies would consider the real-power injection at distribution system level and the reactive power that may be required by DER.

• Power flow calculations to determine real and reactive power flows for voltage controls and distribution planning.

• Short-circuit calculations to determine short-circuit power levels for equipment rating and voltage sag propagation analysis.

3

Dynamic Studies

• Frequency and voltage stability analysis following normally cleared or delayed-cleared faults with consideration of the amount of DER power that may be tripped off-line during the disturbance due to under-voltage, over-voltage, under-frequency, or over-frequency. (Concern)

• Transient stability analysis following normally-cleared or delayed-cleared faults with consideration of fast reactive support from DERs that may improve the transient response of the overall system. (Hope)

4

Dynamic DER Models

• Generic Wind Models– WT1 (Type 1) - wind turbine employing a conventional

induction generator directly connected to the grid.– WT2 (Type 2) – wind turbine employing a wound rotor

induction generator with the variable rotor resistance control.

– WT3 (Type 3) - wind turbine employing a doubly fed induction generator (DFIG) with the active control by a power converter connected to the rotor terminals.

– WT4 (Type 4) - wind turbine employing a generator connected to the grid via the power converter.

5

Photovoltaic (PV) Model

• The model is largely based on the generic type 4 wind model, WT4, with the added ability to simulate output changes due to solar irradiation.

• PV model is reported to produce greater loss of DER generation than would likely be seen in the real system being simulated.

6

DER Modeling Recommendations

• For long-term planning studies, expected DER deployment levels looking 5-10 years ahead is reasonable.

• Netting of DER with loads is not recommended because the resulting models will misrepresent the impact of DER on power flows and dynamic performance.

• Model explicitly any single DER with a capacity of greater than or equal to 10 MVA.

7

Modular Representation of DER

• Distinguish each DER to resource type to derive meaningful dispatch scenarios rather than worse-case dispatches for planning studies.

• Provide DER per interconnection requirements performance to represent the fundamentally different steady-state and dynamic behavior among future and legacy DERs.

8

9

? ?

NERC Solar Alert II


Agenda Item 7

December 4, 2018

Andrey Oks, Director of Operations Coordination, NPCC, Inc.

Agenda• Background

• Events overview

• Alerts

• Current and future resources and activities


Background• 8/16/2016 Southern California Blue Cut Fire Event

– Inverter-based Resource Performance Task Force (IRPTF)

– NERC Solar Alert I (Level II – Recommendation), June 20, 2017

• 10/9/2017 Southern California Canyon 2 Fire Event

– NERC Solar Alert II, May 1, 2018


Blue Cut Fire Event –8/6/2016

Ad Hoc IRPTF NERC Solar

Alert I –6/20/2017

Canyon 2 Fire Event –

10/9/2017

NERC Solar Alert II –5/1/2018

8/16/2016 Blue Cut Fire Event• What happened

4

Map of the Affected Area and Blue Cut Fire Location

Source: 1,200 MW Fault Induced Solar Photovoltaic Resource Interruption Disturbance Report, June 2017, available -https://www.nerc.com/pa/rrm/ea/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_Interruption_Final.pdf

https://www.nerc.com/pa/rrm/ea/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_Interruption_Final.pdf

IRPTF• Origins

–Ad hoc task force

• Purpose

• Activities

• Deliverables

• Membership


8/16/2016 Blue Cut Fire Event• What we learned

– Finding 1: PV Disconnect Due to Error in Frequency

– Finding 2: Momentary Cessation Due to Low Voltage

– Finding 3: NERC Alert Warranted

– Finding 4: Potential Inconsistencies

6

Source: 1,200 MW Fault Induced Solar Photovoltaic Resource Interruption Disturbance Report, June 2017, available -https://www.nerc.com/pa/rrm/ea/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_Interruption_Final.pdf

https://www.nerc.com/pa/rrm/ea/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_/1200_MW_Fault_Induced_Solar_Photovoltaic_Resource_Interruption_Final.pdf

NERC Alerts

• What is it?

• What is it used for?

• How is the tool used?


NERC Solar Alert I• NERC Solar Alert I (Level II –Industry

Recommendation)– Loss of Solar Resources during Transmission Disturbances

due to Inverter Settings, June 20, 2017

• Recommendations– #1 - no trip due to an erroneous instantaneous

frequency measurement

– #2 – reduce time delay to restore output

– #3 – SA and Plan for unmitigated resources

– #4 – Information gathering


10/9/2017 Canyon 2 Fire Event• What happened

9

Source: 900 MW Fault Induced Solar Photovoltaic Resource Interruption Disturbance Report, February 2018, available -https://www.nerc.com/pa/rrm/ea/October%209%202017%20Canyon%202%20Fire%20Disturbance%20Report/900%20MW%20Solar%20Photovoltaic%20Resource%20Interruption%20Disturbance%20Report.pdf

https://www.nerc.com/pa/rrm/ea/October%209%202017%20Canyon%202%20Fire%20Disturbance%20Report/900%20MW%20Solar%20Photovoltaic%20Resource%20Interruption%20Disturbance%20Report.pdf

10/9/2017 Canyon 2 Fire Event• What we learned

– Finding 1: No Erroneous Frequency Tripping ✓– Finding 2: Continued Use of Momentary Cessation– Finding 3: Ramp Rate Interactions with Momentary Cessation– Finding 4: Interpretation of PRC-024-2 Voltage Ride-Through

Curve– Finding 5: Instantaneous Voltage Tripping and Measurement

Filtering– Finding 6: Phase Lock Loop Synchronization Issues– Finding 7: DC Reverse Current Tripping– Finding 8: Transient Interactions and Ride-Through

Considerations

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Source: 900 MW Fault Induced Solar Photovoltaic Resource Interruption Disturbance Report, February 2018, available -https://www.nerc.com/pa/rrm/ea/October%209%202017%20Canyon%202%20Fire%20Disturbance%20Report/900%20MW%20Solar%20Photovoltaic%20Resource%20Interruption%20Disturbance%20Report.pdf

https://www.nerc.com/pa/rrm/ea/October%209%202017%20Canyon%202%20Fire%20Disturbance%20Report/900%20MW%20Solar%20Photovoltaic%20Resource%20Interruption%20Disturbance%20Report.pdf

NERC Solar Alert II• NERC Solar Alert II (Level II –Industry

Recommendation)– Loss of Solar Resources during Transmission Disturbances due to Inverter

Settings, May 1, 2018

• Recommendations– #1.a – Accurately current models– #1.b – Elimination/expanded threshold of Momentary Cessation– #2 – Ramp Rate Interactions with Momentary Cessation– #3 – Voltage trip settings – #4 – DC reverse current protection settings – #5 – Inform appropriate entities (RCs, BAs, TOPs, PCs and TPs)– #6.a, b – Dynamic models evaluation, update and assessment of

reliability risks


NERC Solar Alert II• Industry Response

(Source NERC Alert II report and September 2018 Operating Committee presentation)



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– Northeastern North America (NPCC Region) Response

• ~ 200MW of BES PV Resources (Ontario)

• No other Areas have any BES PV

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Reliability

Coordinator

area

Nameplate Solar

Capacity (MW)

Maritimes 0

New England 941

New York 32

Ontario 380

Québec 0

Total 1353

NPCC Solar Capacity

Source: 2018-2019 NPCC Winter Reliability Assessment

Current and FutureResources and Activities

• IRPTF/ERO– Reliability Guideline: BPS-Connected Inverter-Based Resource

Performance, September 12, 2018– Webinars (https://www.nerc.com/comm/PC/Pages/Inverter-

Based-Resource-Performance-Task-Force.aspx) • Inverter-Based Resource Disturbance Analysis, 2/15/2018• Loss of Solar Resources during Transmission Disturbances due to

Inverter Settings - II, 5/11/2018• Modeling of Momentary Cessation and Voltage Ride-Through,

7/20/2018

• Evaluation of the Alert II data by the ERO/IRPTF• December 2018 Operating Committee

– Executive Action on IRPTF PRC-024-2 Gaps Whitepaper– Standard Authorization Request (SAR) - PRC-024-2 Generator

Frequency and Voltage Protective Relay Settings


Source: September 2018 Operating Committee IRPTF update presentation, modified with the “Approved” Guideline status.

https://www.nerc.com/comm/PC/Pages/Inverter-Based-Resource-Performance-Task-Force.aspx

Questions?
