der interconnection requirement whitepaper · 2018. 4. 6. · lm3 lm1 ride-through lc6 lc5 lc3 lc4...

© 2015 Electric Power Research Institute, Inc. All rights reserved.

Jens C. BoemerLeading research on the grid integration

of renewable and distributed energy resources

NERC ERSTF, AtlantaMarch 11th, 2015

DER Interconnection Requirement Whitepaper

Recommended Settings for Voltage and Frequency Ride-Through of

Distributed Energy Resources

2© 2015 Electric Power Research Institute, Inc. All rights reserved.

Background

Bulk and distribution system needs

EPRI‘s Recommended Minimum Requirements & Settings

Conclusions

Discussion– NERC coordination with

revision of IEEE Standard 1547 ???

Content


Background

Interconnection Standards and Grid Codes are one out of 3 key EPRI research areas in the context of the Integrated Grid

Why does EPRI engage in this topic?

Benefit/Cost Framework

Inter-connection Technical

Guidelines

Grid Planning & Operations

Collaboration with All StakeholdersIncluding Regulatory/Policy Needed


Background

IVGTF Report (Task 1-7), Dec. 2013– Gives a solid rationale for ride-through requirements for all

DER, regardless of size or technology– In the short-term, NERC should engage in current efforts to

revise DER interconnection standards Recommends explicit low and high voltage & frequency

ride-through requirements Gives “examples” for VRT and FRT curves / tables

– In the longer-term, NERC should establish a coordination mechanism with IEEE Standard 1547 … ???

NERC PRC-024-2, Jan. 2015– Standard for Generator Frequency and Voltage Protective

Relay Settings– Limited to NERC jurisdiction, i.e., Bulk Electric System I4,

Dispersed power producing resources: > 75 MVA (gross nameplate rating) PCC at a voltage of 100 kV or above

– Not an explicit ride-through standard! Units may trip due to internal protection functions, e.g.,

out-of-step, loss-of-field, instab. in pwr. conv. ctrl. equipm.

What are the related NERC activities / publications?


BackgroundWhat is the status of the revision of the IEEE Standard 1547?

2005

2011

FERC SGIP (Small Generator Interconnection Procedure)

IEEE 1547-20032003

2000 California Rule 21

Updated California Rule 21(consistent with IEEE 1547-2003)

IEEE 1547a-20142014

2015

2016

Updated California Rule 21 & HECO’s FVRT Requirements

(go far beyond IEEE 1547a-2014)

2018IEEE 1547rev-20xx

Revisions in IEEE 1547a-2014: Allows DER1 to support voltage

via real/reactive power Permits frequency/watt functions Optional widening of trip limits and

clearance times Dynamic trip limits now allowed

Refine in IEEE 1547rev-20xx: Ride-through Voltage Support Communication/Control Anti-islanding detection

1 distributed energy resources


Bulk and Distribution System Needs

Transmission Distribution

… are quite different but can only be approached in an integrated way.

Voltage/Reactive Power Power quality: voltage limits/power factor

Frequency Stability

Health & Safety: protection coordination/anti-islanding


Bulk and Distribution System Needs

Transmission Distribution

… are quite different but can only be approached in an integrated way.

Future Technical Guidelines Must Equally Address Bulk and Distribution System Needs

Voltage/Reactive Power Power quality: voltage limits/power factor

Health & Safety: protection coordination/anti-islanding

Frequency Stability



Three types of zones Zone 1: Must Trip Zone 2: Ride-Through or Trip is

Allowed Zone 3: Ride-Through

Various operating zones/modes “Passive” ride-through “Active” ride-through

– “as you were”– “smart”

Event Duration

Appl

icab

le V

alue

(p.u

.)

1.0 p.u.

Must Trip

LC1

LM5LM4

LM2LM3

LM1

Ride-Through LC6LC5

LC3 LC4

LC2

HM5HM4

HM3HM2

HM1

HC3HC4

HC2HC1

Must Trip

Ride-Through or Trip is Allowed


Appl

icab

le V

alue

(p.u

.)

1.0 p.u.

LC1

LC6LC5

LC3 LC4

LC2

HC3HC4

HC1 HC2

Event Duration

Zone A Mode

Zone B Mode

Zone C Mode

Ride-Through


What is the high-level concept behind these recommendations?



Recommendations should be technology-neutral

Guiding principles for frequency ride-through were– DER should not be tripped before under-frequency load

shedding (UFLS) is fully activated and before the frequency is restored following a major disturbance;

– DER should not be tripped during over-frequency events likely to occur during contingency situations;

– DER should comply with a minimum ride-through requirement

No droop characteristic (frequency-watt) as a minimum requirement, rather an advanced requirement

What are the recommendations for frequency ride-through?


EPRI‘s Recommended Minimum Requirements & SettingsWhat are the recommendations for frequency ride-through?

56.0

56.5

57.0

57.5

58.0

58.5

59.0

59.5

60.0

60.5

61.0

61.5

62.0

62.5

63.0

0.01 0.1 1 10 100 1000

Freq

uenc

y (H

z)

Time (s)

Normal Operation

aHFRT - "as you were"

aLFRT - "as you were"

Tripped

Tripped

65.0 Hz 65.0 Hz

300 s

10 s0.16 s

10 s

60.5 Hz

61.5 Hz

50.0 Hz

59.5 Hz

0.16 s 10 s

50.0 Hz

58.5 Hz

300 s10 s

12 s

Legend

range of adustability

default value

operating region



Recommendations should be technology-neutral

Guiding principles for voltage ride-through– Consider the geographic extension of a voltage dip at bulk system

level and the affected DER capacity;– Consider the voltage dip propagation from bulk system to

distribution level;– Minimum trip times and LVRT duration should consider bulk system

fault clearing times for both normally cleared faults (by primary protection) and stuck breaker faults cleared with delay (by remote backup);

– Keep the impact of LVRT requirements on the Area EPS as low as possible;

– Ensure a fast restoration of pre-fault real power output after disturbances.

What are the recommendations for voltage ride-through?


EPRI‘s Recommended Minimum Requirements & SettingsWhat are the recommendations for voltage ride-through?

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

1.10

1.20

1.30

0.01 0.1 1 10 100 1000

Volta

ge (p

.u.)

Time (s)

aHVRT - "as you were"

Tripped1.30 p.u. 1.30 p.u.

13 s0 s 0.16 s

1 s

1.10 p.u.1.20 p.u.

0.20 p.u.

0.70 p.u.

0 s1 s

0.20 p.u.

0.45 p.u.

21 s2 s

Legend


default value

operating region

Normal Operation

pHVRT

aLVRT - "as you were"

pLVRT OR aLVRT - "as you were"

0.20 p.u.

11 s

Tripped

1 s0.50 p.u.

0.32 s

0.32 s


Conclusions

NERC’s IVGTF Report (Task 1-7), Dec. 2013, has set the scene for voltage & frequency ride-through requirements;

CA Rule 21 and HECO’s F/VRT requirements are leading, but IEEE Standard 1547 is speeding up thanks to involvement of EPRI;

EPRI proposes minimum requirements & settings for voltage and frequency ride-through of DER and engages in discussions with relevant stakeholders;

These minimum requirements could define the baseline of F/VRT in IEEE 1547rev-20xx to address both bulk and distribution system needs;– Advanced requirements could be defined in “higher” performance classes;

How to further coordinate NERC input with the revision of the IEEE Standard 1547?


Together…Shaping the Future of Electricity

Feel free to ask questions…

Jens C. Boemer, email [email protected] , phone +1.206.471.1180

mailto:[email protected]


DiscussionHow to coordinate NERC input with the revision of the IEEE Standard 1547?

2015 2016

Common Definitions

High-level Ride-

Through Concept

Draft Ride-Through

Trip settings & ranges

Permissive Ride-Through: “passive” or “active” Ride-Through

Continuous Operation

Smart Ride-

ThroughPermissive Operation:

1. duration 2. applicable voltageReturn to Service

Momentary Cessation

“active” Ride-Through - “as you were”

“Energize”

Mandatory Operation

state transition


Example for Advanced RequirementsFault induced delayed voltage recovery (FIDVR) in distribution systems with high A/C loads

1.0

0.8

0.9

1.1

1

2

34

5

6

2 Delayed recovery as stalled A/Cs disconnect

3 Overvoltage due to capacitors still on line

4 Capacitors switch off due to overvoltage

5 A/C loads come back

6 Undervoltage due to capacitors off line

1 Fault & fault clearance

5 to 30 sec.

Time [s]

Volta

ge [p

.u.]

w/o “smart” ride-through

with “smart” ride-through

FIDVR can be mitigated by “smart” LVRT


P1547 III) General Requirements 2 – Ride-Through

Consensus reached within Sub-W.G. / proposal to Overall Working Group

Topic is still under discussion within Sub-W.G.

Alternative positions within Sub-W.G.

Traffic light indicate where the process stands



Reference point for requirements– Point of Common Coupling (PCC), or– Point of DER Connection / Electrical Connection Point

Differentiation of requirements– Technology classes, e.g., directly-connected synchronous generators, inverter-coupled generation

– Performance classses, e.g., minimum requirements for bulk system reliability, advanced requirements for distribution system power quality

Fundamental open decisions



Continuous Operation (“normal operation”) Trip (industry standard term)

– “Cease to Energize” (from IEEE Std. 1547-2003) Ride Through

– Operating RegionPermissive Operation (“passive” or “active” ride-through)Momentary Cessation (“passive ride-through”)Mandatory Operation (“active” ride-through)

– “Return to Service” “Energize” (term already reserved by Area EPS)

Manufacturer stated accuracy

Common terms to describe ride-through behavior



For voltage ride-throughLatest proposal (Feb 26) – work in progress

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

1.10

1.20

1.30

0.01 0.1 1 10 100 1000

Volta

ge (p

.u.)

Time (s)

Momentary Cessation or Volt/Watt

Tripped1.30 p.u. 1.30 p.u.

13 s0 s 0.16 s

1 s

1.10 p.u.1.20 p.u.

0.00 p.u.

0.88 p.u.

0 s1 s

0.00 p.u.

0.45 p.u.

21 s2 s

Legend


default value

operating region

Continuous Operation

Mandatory Operation

Permissive Operation

Tripped

0.16 s

0.32 s

Measure 4• Frequency nadir as a function of unit trip size

at similar load (net load) conditions;• For example, low net load conditions are of

interest since synchronous inertia is lower and less generators with governors in service are available.

• Other system conditions may also be of interest

Measure 4

Inertial and Frequency Response Estimator tool (IFRET)

• Estimates inertial frequency response to disturbance in MW/0.1 Hz• Allows in real time to estimate Point A to Point C frequency deviation for a

generation trip• Uses real time information about committed conventional generation (H

and MVA), system load data, wind penetration (as % of load), available spinning reserves

• Uses linear equations (e.g. see previous slide) obtained from historical generation trip events at similar set of conditions.

• Can provide System Operator with better awareness of the potential frequency deviation due to loss of a unit.

• Can be used as a decision support tool. The System Operator can commit additional units to provide adequate Inertia support in normal operations based on IFRET result.

• During 2010, IFRET was running in the control room, since Nodal Market the tool has been used intermittently, needs update with recent frequency events.

Change in System Frequency and MW loss relationship for Data-Set II

Change in System Frequency and MW loss relationship for Data-Set I

ERSTFLoads and Resources Balance

Clyde Loutan, Senior Advisor – Renewable Energy Integration, CAISO

Jacksonville, Florida

March 11 & 12

RELIABILITY | ACCOUNTABILITY2

Loads and Resources Team

Subgroup Lead Company Email

Clyde Loutan CAISO [email protected]

Subgroup Members

Amir Najafzadeh NERC [email protected]

Brendan Kirby Kirby Consulting [email protected]

Dave Devereaux IESO [email protected]

Ed Scott Duke Energy [email protected]

Jay Ruberto First Energy [email protected]

Layne Brown WECC [email protected]

Michael McMullen MISO [email protected]

Michael Milligan NREL [email protected]

Noha Abdel-Karim NERC [email protected]

Pooja Shah NERC [email protected]

Ron Carlsen Southern Company [email protected]

Todd Lucas Southern company [email protected] Siegrist Brickfield, Burchette, Ritts & Stone, P.C. [email protected] Dariush Shirmohammadi California Wind Energy Association [email protected] Tuohy EPRI [email protected]

















CAISO: 1-Hour Upward Ramping Needs

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec2011_1h 3,935 3,630 3,271 2,897 2,951 2,637 3,137 2,933 3,004 3,514 3,746 4,5062012_1hr 3,875 3,394 3,428 2,959 2,736 2,606 2,695 2,766 3,143 3,240 5,358 4,3522013_1hr 4,524 3,557 3,224 2,893 3,072 3,401 2,723 2,380 2,964 3,406 3,759 4,5672014_1hr 3,862 3,374 3,064 3,653 2,527 3,128 2,446 2,320 2,848 3,012 3,192 4,2352018_1hr 5,790 6,545 6,298 5,459 4,515 4,220 3,976 4,774 5,999 6,084 6,794 7,420

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

MW

Maximum 1-Hour Upward Ramps


CAISO: 3-Hour Upward Ramping Needs

Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec2011_3hr 6,766 6,067 5,688 5,942 6,732 7,822 7,702 7,251 6,767 6,433 7,098 2012_3hr 7,173 7,028 5,774 6,278 5,543 6,367 7,410 6,591 6,422 6,062 7,2112013_3hr 7,171 6,736 5,881 6,096 8,745 6,426 6,024 6,591 6,609 7,355 8,3432014_3hr 6,170 5,755 5,363 6,394 6,177 6,559 5,879 7,862 5,952 5,844 6,4942018_3hr 15,048 14,100 11,332 11,022 10,769 10,390 12,143 14,174 12,509 15,190 17,179

0

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

18,000

20,000

MW

Maximum 3-Hour Upward Ramps


CAISO: 1-Hour Downward Ramping Needs

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec2011_1h -2,823 -2,939 -2,751 -2,758 -3,374 -3,771 -3,994 -3,920 -4,758 -3,267 -2,719 -3,2522012_1hr -3,118 -7,240 -2,940 -3,056 -3,458 -3,457 -4,049 -3,919 -4,220 -3,972 -4,547 -3,0432013_1hr -3,236 -2,663 -3,004 -3,194 -4,043 -3,820 -4,398 -4,140 -3,926 -3,026 -2,849 -3,0442014_1hr -2,506 -2,510 -2,601 -3,554 -4,170 -3,728 -3,826 -3,830 -4,248 -3,453 -2,426 -2,7952018_1hr -4,014 -4,078 -5,344 -4,593 -4,901 -4,672 -4,955 -5,316 -5,659 -4,997 -4,638 -4,590

-8,000

-7,000

-6,000

-5,000

-4,000

-3,000

-2,000

-1,000

0

MW

Maximum 1-Hour Downward Ramps


CAISO: 3-Hour Downward Ramping Needs

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec2011_3hr -7,091 -7,118 -6,711 -6,690 -8,276 -9,248 -10,362 -9,919 -11,684 -8,162 -6,900 -8,202 2012_3hr -7,083 -7,363 -6,900 -7,472 -8,472 -7,734 -9,804 -10,775 -10,195 -10,256 -6,865 -7,6802013_3hr -7,600 -6,794 -6,806 -7,769 -9,908 -10,357 -10,023 -10,438 -10,136 -6,765 -6,643 -7,2272014_3hr -6,258 -6,263 -6,350 -9,330 -10,538 -9,395 -9,813 -10,128 -10,981 -8,996 -6,346 -7,1132018_3hr -8,815 -9,106 -9,086 -9,418 -12,068 -10,684 -11,676 -12,871 -13,143 -10,223 -8,541 -9,572

-14,000

-12,000

-10,000

-8,000

-6,000

-4,000

-2,000

0

MW

Maximum 3-Hour Downward Ramps


BC Hydro 1-Hour Ramps


BC Hydro 3-Hour Ramps


Duke Energy Florida (DEF)


Duke Energy Carolinas (DEC)


Duke Energy Progress (DEP)


Measure 6Ramping Capability Measures

The historical and projected maximum one-hour up, one-hour down, three-hour up, and three-hour down net load ramps (actual load less production from VERs) using one minute data.

Year One-hour Up One-hour down Three-hour Up Three-hour Down

2011 6166 -6325 11714 -100962012 5560 -4376 10385 -96142013 4192 -4521 9034 -90722014 4423 -3868 9911 -92362015 4423 -3868 9911 -92362016 4423 -3868 9911 -92362017 4423 -3868 9911 -9236

YearWind

Capacity, MW PV, MW2011 0 02012 0 02013 202 462014 404 502015 404 11822016 654 11822017 654 1670

Southern Company


Southern Company


Southern Company

Todd Lucas


PJM


PJM

Ken Schuyler

der interconnection requirement whitepaper · 2018. 4. 6. · lm3 lm1 ride-through lc6 lc5 lc3 lc4...

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