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ISO-NE PUBLIC
1 2 / 1 9 / 2 0 1 7 | W E S T B O R O U G H , M A
Osman Bileya L E A D E N G I N E E R
2018 Load Power Factor Standards
2016/2017 Load Power Factor Audit
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Goals
• Describe OP-17 Load Power Factor (LPF) Correction program
• Review the 2016/2017 LPF Survey results
• Share the revised 2018 LPF Standards
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OP-17 LPF CORRECTION PROGRAM
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OP-17 LPF Correction Program
• The LPF correction program is described in Operating Procedure # 17
• The LPF correction program is managed by the Voltage Task Force (VTF)
• New England system is divided up into eleven sub-areas for the purposes of this LPF correction program
• Each area is assessed individually to determine its own reactive needs
• LPF Standards are set based on each area’s reactive needs
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Graphical Representation of the 11 LPF Areas
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Annual Load Power Factor Survey
• ISO-NE and VTF are responsible for: – Administering the annual LPF survey – Evaluating and reporting results – Requesting remedial action plans from Market Participants
• Every year specific historical hours are selected from the previous year
• Each load serving Participant (as defined in OP17 Appendix C) is tasked with submitting LPF data for the selected historical hours
• Participant’s surveyed LPFs are compared to its area’s LPF Standard
• The degree of noncompliance for each Participant is identified in terms of surplus or shortfall of reactive capability
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Example of Load Power Factor Standard and Survey
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Annual Load Power Factor Survey
• The annual LPF Survey Program accomplishes two goals:
1. Audit load serving Participants’ compliance with the current LPF standards
2. Forecast load serving Participants’ compliance with the new standards if the current standards are revised/updated
• OP-17 LPF correction program cited by NERC as an Example of Excellence
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2016/2017 LPF SURVEY RESULTS
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2016/2017 Load Power Factor Survey Results
• Seventy six (76) participants submitted LPF audit data for six loads points identified by ISO New England:
– Spring Light load (9,059 MW)
– Summer Intermediate load (22,537 MW)
– Summer Peak load (25,596 MW)
– Fall Light load (9,031 MW)
– Winter Intermediate load (17,295 MW)
– Winter Peak load (19,570 MW)
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Fully Compliant Participants in the 2016/2017 Audit Period
• In the 2016/2017 audit period 36 participants were fully compliant:
Boston: NSTAR dba Eversource Central Mass/Harriman : Fitchburg Gas & Electric, Shrewsbury, Templeton,
Hudson, Princeton Connecticut area: Bozrah Light & Power, The United Illuminating Company,
CL&P dba Eversource Maine: Emera Maine (Bangor Hydro), CMP New Hampshire: Littleton, PSNH dba Eversource, Unitil Energy Systems Northeast Mass: Danvers, Ipswich, Littleton, Middleton, Peabody, Reading,
Rowley Rhode Island: Narragansett Southeast: Nantucket, Hingham, Mansfield, Norwood, NSTAR dba Eversource SWCT: The United Illuminating Company, Third Taxing District-Norwalk Vermont: Liberty (Granite State Electric - GS WEST), Green Mountain Power,
New Hampshire Electric Coop, VELCO Western Mass: Chicopee Electric Light, Holyoke Gas and Electric, South
Hadley
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2016/2017 LPF Survey Results
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2016/2017 LPF Survey Results Cont’d
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2016/2017 LPF Survey Results Cont’d
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2016/2017 LPF Survey Results Cont’d
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2016/2017 LPF Survey Results Cont’d
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2016/2017 LPF Survey Results Cont’d
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2016/2017 LPF Survey Results Cont’d
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Forecast Compliance
• 5 out of 11 Areas are compliant (no reactive deficiency) based on the 2018 LPF standards
– The compliant areas are Connecticut, Maine, Rhode Island, Southwest
Connecticut, and Vermont – The non-compliant areas are Boston, Central MA/Harriman, New
Hampshire, Northeast Massachusetts, Southeast Massachusetts, and Western Massachusetts
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REVISED 2018 LPF STANDARDS
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Reasons for Revising LPF Standards
• Changes in area voltage/reactive performance due to transmission changes:
– New transmission lines
– New bulk transformers
– Generation Retirement
– Changes in generator reactive capability
– Additional static or dynamic reactive compensation
– Changes in transfer conditions
– Load growth since last Area LPF study
– Change of Area definition
– Revision of “Testing Criteria” assumptions
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Revised 2018 LPF Standards
• Revised 5 out of the 11 Areas’ LPF Standards for 2018 due to transmission system upgrades expected to be in-service by 2018:
– Boston
– Northeast Massachusetts
– Connecticut
– Southwest Connecticut
– Vermont
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Summary of Upgrades
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Vermont
• CT River Valley Project upgrades
– installation Ascutney SVC (+50/-25 MVAr)
– 115 kV cap bank split
– 46 kV line re-conductoring
Northeast MA
• Addition of Footprint combine cycle generation at Salem station (715 MVA)
• Greater Boston Upgrades
– New 345 kV line (Scobie to Tewksbury)
– New 345 kV cable (Woburn to Wakefield Jct) and associated reactors (2x160 MVAR)
– Reconfigure K Street 345 kV station to a ring bus and add a new 345 kV reactor
– Additional autotransformers at Mystic and Sudbury
– Operating one Wakefield Junction autotransformer as normally open
– Multiple 115 kV capacitor additions
– 115 kV line re-conductoring
Boston
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Summary of Upgrades Cont’d
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Connecticut • Addition of Towantic Energy combined cycle generation
(800 MVA) and Wallingford 6 & 7 units (138 MVA)
• Greater Hartford Central CT project – Split of 348 line 3-terminal line into two 345 kV lines – Addition of 2nd autotransformer at Haddam and Barbour Hill – Addition of 115 kV capacitor banks at several stations – Addition of new 115 kV lines – Addition of new synchronous condenser at Stony Hill – Retiring of Bates Rock & Stony Hill DVARs
Southwest CT
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Testing Criteria - Minimum LPF standard
• Setup low voltage bias cases at NE loads levels 18,000 and 28,000 MW
• Screen all OP-19 contingencies in the bias case to find the worst contingency resulting in either lowest voltage profile or biggest MVAR demand in the study area
• With the worst contingency modeled, adjust the study area’s LPF uniformly until either a low voltage or net 0-MVAR interchange violation is met
• LPF standard will be set based on the most limiting criterion (low voltage or net 0-MVAR interchange )
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Testing Criteria - Maximum LPF standard
• Setup high voltage bias cases at NE load levels 9,000 and 18,000 MW
• Screen all OP-19 contingencies in the bias case to find the worst contingency resulting in either highest voltage profile or biggest MVAR surplus in the study area
• With the worst contingency modeled, adjust the study area’s LPF uniformly until either a high voltage or net 0 MVAR interchange violation is met
• Conduct facility out testing
• LPF standard will be set based on the most limiting criterion (high voltage or net 0-MVAR interchange violation) – Note with the exception of Boston area, net 0-MVAR interchange violations
resulting in a lagging maximum LPF standard will be waived and instead Unity LPF standard will be applied
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2018 LPF Studies Results
Area Minimum LPF
Standard Limiting Criteria Maximum LPF
Standard Limiting Criteria
Vermont Shoulder: 0.8590
Peak : 0.9510 low voltage
Light: 1.0140 Shoulder : 1.0220
Net 0-MVAR interchange
Northeast MA Shoulder : 0.9600
Peak : 0.9710 Net 0-MVAR interchange
Light : 1.000 Shoulder : 1.000
Unity LPF (violated 0-MVAR)
Boston Shoulder : 0.8887
Peak : 0.9020 Net 0-MVAR interchange
Light: 0.9530 Shoulder : 0.9877
Net 0-MVAR interchange
Connecticut Shoulder : 0.9580
Peak: 0.9630 Net 0-MVAR interchange
Light: 1.000 Shoulder: 1.0263
Net 0-MVAR interchange
Southwest CT Shoulder : 0.8970
Peak : 0.9500 Shoulder: 0-MVAR Peak: low voltage
Light: 1.000 Shoulder: 1.000
Unity LPF (violated 0-MVAR)
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Comparison of 2018 LPF Standards to Current LPF Standards
Area Minimum standards Maximum standards
Vermont
2018 standards are tighter due to lower hydro generation dispatch in the area and less number
of Granite SCs online to match closely with operating conditions.
Similarly, 2018 maximum standards are tighter than the Current Maximum LPF standards (less hydro and
Granite SC online).
Northeast MA
2018 standards are slightly improved due to system upgrades in the area.
2018 standards are tighter (unity) due to area’s inability to absorb MVAR generated locally. System upgrades do not include reactive resource to help
with absorbing all area MVAR exports.
Boston
2018 standards are slightly tighter due to less area generation being online at the lower NE shoulder load level used for testing this year.
2018 Maximum LPF standards are slightly more restrictive due to testing at lower New England load levels and the overall lower I2X losses in the area due
to the system upgrades.
Connecticut 2018 standards are slightly improved due to addition of capacitors and 115 kV lines in the
area as part of GHCC.
2018 standard are similar to the current standards since the system upgrades do not help with MVAR
absorption in the area.
Southwest CT
2018 standards are greatly improved due to addition of capacitors in the area as part of
GHCC.
2018 standards are tighter (unity) due to area’s inability to absorb MVAR generated locally. System upgrades do not include reactive resource to help
with absorbing all area MVAR exports.
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APPENDIX I 2018 LPF Standard Plots
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APPENDIX II 2018 Study Areas - list of upgrades
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Vermont – 2018 LPF Standards
The reason for revising Vermont’s LPF standards is to perform a five year review and to incorporate the CT River Valley Project. Here are the key upgrades:
– A rebuild of the K31 line from Ascutney to Coolidge
– The installation of the Ascutney SVC (+50/-25 MVAr)
– The split of the Hartford 25 MVAR cap bank into two 12.5 MVAR cap banks
– The rebuild of the Chelsea substation to a three breaker ring configuration
– 46 kV line reconductoring
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Northeast Massachusetts – 2018 LPF Standards • The reason for revising NEMA’s LPF standards is Greater Boston
upgrades. Here are the key upgrades:
– New 345 kV cable (3136) from Woburn substation to the Wakefield Junction
substation. Woburn 160 MVAR 345 kV reactor, Wakefield 160 MVAR 345 kV reactor. (ISD 6/2019, will be considered in-service in the NEMA Area Year 2018 Load Power Factor Standard Study)
– New 345 line (3124) from Scobie to Tewksbury
– Addition of Footprint combine cycle units at Salem (~750 MW)
– Reconfigure one of the four existing Wakefield Junction autotransformers to be normally open
– Eliminate the double circuit tower on the 115 kV lines F-158N and Q-169
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Northeast Massachusetts – 2018 LPF Standards • Some additional NEMA upgrades:
Reconductor 115 kV lines:
– M-139 line from Tewksbury to Billerica Tap to Pinehurst to N. Woburn Tap
– Y-151N and Y-151 lines from Power Street Substation to Dracut
– N-140 line from Tewksbury to Pinehurst to N. Woburn Tap
– F-158N line from Golden Hills to Maplewood and upgrade terminal equipment at Maplewood
– F-158S overhead line from Maplewood to Everett with terminal equipment replacement at Everett
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Boston – 2018 LPF Standards • The reason for revising Boston’s LPF standards is Greater Boston
upgrades. Here are the key upgrades:
– New 345 kV cable (3136) from Woburn substation to the Wakefield Junction
substation. Woburn 160 MVAR 345 kV reactor, Wakefield 160 MVAR 345 kV reactor. (ISD 6/2019, will be considered in-service in the Boston Area Year 2018 Load Power Factor Standard Study)
– Woburn 345/115 kV autotransformer replacement with a higher rating transformer; 345 kV and 115 kV breaker additions at Woburn
– Sudbury 230/115 kV autotransformer addition and new 230 kV switchyard
– New 345 kV (3124) line from Scobie to Tewksbury
– Waltham reconfiguration
– Operate K Street 345 kV as normally closed station
– K Street 345 kV - new shunt reactor (160 MVAR) and convert straight-bus to a ring-bus
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Boston – 2018 LPF Standards • Additional upgrades:
– Mystic second 345/115 kV autotransformer addition and bus reconfiguration
– Mystic 115 kV bus tie breaker #7 will be operated normally closed
– Add a second Mystic-Woburn 115 kV cable to create a bifurcated 211-514 Mystic-Woburn 115 kV circuit
– Split existing DCT 110-522/240-510 from Baker St. to Needham
– Open 115 kV lines 329-510/511 from Mystic to Somerville and 250-516/517 from Chatham to Seafood
– Kingston Street upgrades to create a second normally closed 115 kV bus tie and 345 kV reconfiguration
– North Cambridge equipment termination changes to mitigate 115 kV stuck breaker 5 and 10 contingencies
– New 115 kV capacitors at Sudbury, Hartwell, and Newton Station
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Connecticut – 2018 LPF Standards The reason for revising Connecticut’s LPF standards is the Greater Hartford Central Connecticut project. Here are the key upgrades:
– Towantic combined cycle units (820 MW)
– Addition of units 6 & 7 at Wallingford (51 MW each)
– Barbour Hill second autotransformer addition
– Haddam second autotransformer addition and 348 no longer 3 terminal line
– Rood Ave rebuild
– New 115 kV capacitors at Oxford, Hopewell, Green Hill, West Brookfield, West Side, and Berlin
– Plumtree 115 kV capacitors (2) & new 115 kV line
– Rocky River capacitor reduction
– Stony Hill synchronous condenser addition and capacitor terminal modification
– Bates Rock & Stony Hill DVAR retirements
– New line from Frost Bridge to Campville
– New line from Southwest Hartford to Newington
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Southwest Connecticut – 2018 LPF Standards The reason for revising Southwest CT’s LPF standards is
Greater Hartford Central Connecticut upgrades. Here are the key upgrades in the UI area:
– Removal of Sackett PARs
– New 115 kV capacitors at Ansonia and Hawthorne
– Pootatuck ring bus & 115 kV capacitor
– Mix Avenue 115 kV capacitor & series reactor
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