GUIDE TO IEEE 1547-2018Where Do We Start?

Interconnecting Distributed Resources with Electric Power Systems (2003)

16 pp

Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power

Systems Interfaces (2018)

Published April 2018

➢Starting Point for Applying

Standard

➢Idea From T&D MAG

➢Draft Completed in September

➢Delayed-IEEE Copyright Issues➢NRECA Guide to IEEE 1547-2018 ➢IEEE Standards: 1547-2018

➢10 MVA Limit is Gone

➢Voltage Regulation Capability

➢Interoperability Capability Required for All DER

➢Clause on Intentional Islands

➢Disturbance Performance

➢Frequency Droop Requirement

➢Ride-Through (No Trip) Requirements

➢Expanded Ranges of Adjustability

➢Voltage & Frequency Disturbances

•NERC and a few utilities began to advocate

less-sensitive setpoints for tripping:

➢Keep DERs On-Line forDisturbances on BES.

➢Still enable tripping for Safety on Distribution Systems.

Defaults and Ranges of Adjustability

For

Voltage and Frequency Tripping

Covered in Clauses 6.4 & 6.5 of Standard

•Cat I Meets most BES Security needs. Includes small synchronous machines.

•Cat II Harmonized w\NERC PRC-024 (protection settings for BES generators)

•Cat III High-Penetration levels where continued DER operation is needed for Distribution System.

Harmonized w\CA Rule 21.

Q:

A: The Authority Governing Interconnection Requirements - the AGIR

Who Or What Is That?

Well, it Depends…

Defined in IEEE 1547-2018➢Can be a:

• Regulatory Agency• Public Utility Commission• Municipality• Co-Op Board of Directors

Defined in IEEE 1547-2018➢Authority may be delegated to the Area EPS operator or bulk power system

operator.

➢Decisions made by an AGIR should consider various stakeholder interests, including but not limited to:➢Load Customers➢Area EPS operators➢DER operator➢Bulk power system operator.

➢Annex B in Standard outlines considerations for Category Selection.

Still not entirely clear, but expect other players:➢Frequency is biggest concern for BES → NERC

➢PJM already working with their members to develop settings

➢Possible that ISOs will mandate frequency settings with no guidance on voltage

➢Voltage Requirements could then fall on Co-Op Board.

How Close Can You Get?

Considering Voltage Trip…

Pretty Close!

Closest to Original Defaults

Condition Clause 1547-2003 Category I

Voltage Trip Pickup Time

OV2 6.4 1.2 p.u. 0.16 s

OV1 6.4 1.1 p.u. 1.00 s

UV1 6.4 0.88 p.u. 2.00 s

UV2 6.4 0.5 p.u. 0.16 s

Category III

Pickup Time

1.20 p.u. 0.16 s

1.10 p.u. 1.0 s

0.88 p.u. 21.0 s

0.50 p.u. 2.0 s

Category I Category II Category III

Pickup Time Pickup Time

1.20 p.u. 0.16 s 1.20 p.u. 0.16 s

1.10 p.u. 1.0 s 1.10 p.u. 1.0 s

0.88 p.u. 2.0 s 0.88 p.u. 2.0 s

0.50 p.u. 0.16 s 0.50 p.u. 0.16 s

How Close Can You Get?

Considering Frequency Trip…

Different Story!

Closest to Original Defaults

Condition Clause 1547-2003 Closest to 1547-2003

Frequency Trip

OF2 6.5 n/a n/a

OF1 6.5 60.5 0.16 s

* UF1 6.5 59.3 0.16 s

UF2 6.5 n/a n/a

Category I, II and III

61.8 Hz 0.16 s

61.0 Hz 180.0 s

59.0 Hz 180.0 s

57.0 Hz 0.16 s

New Default Settings

➢Voltage Trip is Different in Each Category

➢Frequency Trip Same for All Categories

➢Chosen to Support Bulk Electric System

Condition Clause 1547-2003 Category I

Voltage Trip Pickup Time

OV2 6.4 1.2 p.u. 0.16 s

OV1 6.4 1.1 p.u. 1.00 s

UV1 6.4 0.88 p.u. 2.00 s

UV2 6.4 0.5 p.u. 0.16 s

Category I Category II

Pickup Time

1.20 p.u. 0.16 s

1.10 p.u. 2.0 s

0.70 p.u. 2.0 s

0.45 p.u. 0.16 s

Category III

Pickup Time

1.20 p.u. 0.16 s

1.10 p.u. 13.0 s

0.88 p.u. 21.0 s

0.50 p.u. 2.0 s

Category II Category III

Pickup Time

1.20 p.u. 0.16 s

1.10 p.u. 2.0 s

0.70 p.u. 10.0 s

0.45 p.u. 0.16 s

Category I, II and III

62.0 Hz 0.16 s

61.2 Hz 300.0 s

58.5 Hz 300.0 s

56.5 Hz 0.16 s

Condition Clause 1547-2003

Frequency Trip

OF2 6.5 n/a n/a

OF1 6.5 60.5 0.16 s

* UF1 6.5 59.3 0.16 s

UF2 6.5 n/a n/a

New Ranges of Adjustability

➢V Can Be Set to:✓Effectively Not Trip for Undervoltage (0.0 p.u. @ 21 s); and\or✓Only Trip for Overvoltage >1.20 p.u. @ 13 s)

➢f Can Be Set to Effectively Not Trip- Period.

Question: Volunteers to test 144 V for 13 s in their house?

➢Frequency-Watt Function

➢As Frequency Drops Output Increases

➢Cannot Be Disabled

➢Pre-Set Parameters Which May be Adjusted Based on Standard.

Advanced Features

➢Volt-VAR Control

➢Trip Settings Beyond Defaults

➢Interoperability

Conformance Test Procedures for Equipment Interconnecting Distributed Energy Resources with

Electric Power Systems

➢Needed to Ensure Compliance w\1547 (Base Standard)

➢First Published in 2005

➢63 pp Total

➢Now >265 pp - and Counting!

Encouraging News for Co-Ops

➢Nearly Half is For Manufacturers

➢~75 pp of Evaluation and Commissioning Tests

➢Choose Evaluation & Tests Based On Reference Point of Applicability (RPA)

➢40 pp of Annexes

Article- Overview of IEEE 1547.1

➢Type Testing

➢Production Testing

➢Design Evaluation

➢Installation Evaluation (Pre-Commissioning)

➢Commissioning Tests

➢Periodic Tests

Key Decision for Co-Op:

➢How Much of This Do We Handle In-House?➢Affects Costs in Interconnection Process

➢Borne By DER Owner\Operator?

➢Borne By Co-Op?

Also Affects Interconnection Agreements

Tentative Schedule

➢Early April Final WG Vote

➢Late April Submit Draft to IEEE Standards Assn.

➢May Form Ballot Pool (30 Days)

➢June First Vote

➢July- ? Resolution of Comments & Reballot

➢October Publish IEEE 1547.1-2019

Questions?

Robert W. Harris, PESenior Principal, Transmission & Distribution Engineering

Phone 703-907-5753Cell 571-205-3189

robert.harris@nreca.coop