New England Tie Benefit Discussion – Operational View
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Transcript of New England Tie Benefit Discussion – Operational View
New England Tie Benefit Discussion – Operational View
Peter Brandien, Vice President System OperationsNEPOOL Reliability Committee MeetingJuly 20, 2010
Agenda Items 2.0
Reliability Committee Meeting
July 20, 2010
Overview
• At the June 18 Reliability Committee Meeting:– Discussed system restrictions that limited the New England
overall import capability
– Reviewed NERC Standard requirement to maintain “contingency reserves”
– Attempted to communicate how operating reserves could be allocated internally within New England and in other control areas to comply with Standards
• Review limitations to the New England Import Capability
• Operating Reserve Allocation
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New England Interconnection Ties
• New York AC Ties• 2x 345 kV• 1x 230 kV• 4x 115 kV• 1x DC Converter• 1x 138 kV PST (NNC)
• Hydro Quebec Ties• 2x Asynchronous DC
• New Brunswick• 2x 345 kV
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New England Transmission Transfer Capability (MW)
Interface
HQ Phase 2 1400
HQ Highgate 200
New Brunswick 1000
New York (AC) 1500
Total 4100
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New England Transmission System Import Capability
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New York – New England Interface –Review• Capability to import power to and across the NY-NE
Interface is variable and dependents on transmission margins external to New England
• Operations performed an analysis to determine what level of NY-NE interface flows could be relied upon based on available actual transmission margins when NE was importing power from NY
• The analysis evaluated June through September for the last three years (2007, 2008 & 2009)
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Real Time NY Transfer Capability (MW)
Daily Average Available MW from NY on peak when peak is 08 - 23
Count Average
June July August September June July August September
42 22 39 74 639 1036 1076 1394
4 31 99 48 623 866 923 1247
20 19 66 24 767 853 990 1171
31 113 58 24 855 951 872 1159
9 33 20 11 677 809 1361 1095
14 30 41 58 767 867 797 917
12 18 14 60 746 1076 678 979
40 13 18 44 761 776 891 1248
6 31 27 57 626 676 880 1077
29 19 38 58 927 640 920 1083
6 36 11 95 537 848 1335 1209
2 63 22 83 386 821 1206 1253
6 23 4 55 619 726 487 1193
37 13 6 65 985 1090 994 1178
49 6 13 17 973 955 1300 1225
31 26 36 55 958 874 852 1016
45 76 47 65 838 1023 1173 903
61 14 89 67 868 676 1129 879
51 32 109 83 720 672 1184 901
48 17 22 104 810 547 786 1156
47 17 42 119 831 849 1002 1090
44 18 44 79 678 1371 885 1035
45 1 17 80 920 962 841 980
37 5 33 67 1085 653 720 926
29 7 106 81 746 948 1138 1032
13 28 115 124 815 772 1115 977
64 46 10 128 995 1118 806 1015
60 8 12 137 913 919 937 984
39 50 19 72 655 1362 1187 893
36 40 84 82 712 1060 1252 980
43 76 1183 1263
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NY Transfer Capability Duration Curve
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Real Time NY Transfer Capability (MW)
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Hour
New Brunswick – New England Interface
• Maximum import capability of 1000 MW into Maine
• Full import capability is dependent on numerous Special Protection Schemes
• Internal New England transmission limitations prevent transfers up to full import capability when utilizing all northern generation
• Approximately 350 MW constrained in northern Maine at peak load
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Reductions to Transmission Transfer Capability (MW)
Interface
HQ Phase 2 1400
HQ Highgate 200
New Brunswick 1000
- 350 (Orrington South)
New York (AC) 1300*
- 600 (Central East)
Total 2950
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* Based on historical real time transfer capability
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Operating Reserve Allocation
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NERC Reliability Standard BAL-002-0, Disturbance Control Performance
• Requirement 1. Each Balancing Authority shall have access to and/or operate Contingency Reserve to respond to Disturbances. Contingency Reserve may be supplied from generation, controllable load resources, or coordinated adjustments to Interchange Schedules
• Requirement 3.1. As a minimum, the Balancing Authority or Reserve Sharing Group shall carry at least enough Contingency Reserve to cover the most severe single contingency
• In NPCC, “Contingency Reserves” is referred to as “Ten-minute Reserves”
• NPCC also requires “Thirty-minute Reserves” which shall be at least equal to one-half the second contingency source loss
– Shall restore thirty-minute reserve within four hours if it becomes deficient
System Response following a Source Loss
• Following a source loss in New England, most of the generation inertial response is from west of New England
• This generation response will show up as increased power flows into New England on the New York ties
• Neighboring areas must operate their system recognizing this response
• 30% of this power will flow across the NY Central/East Interface because of the inertial response
• New England must restore the external ties back to the scheduled power flows within 10 minutes
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Operating Reserve Allocation
• The NERC Standard allows for reserves to be allocated to coordinated adjustments to Interchange Schedules
• Under expected capacity shortage conditions, if we assume that New England can arrange with New York to take advantage of the inertial response and some additional level of shared activation of reserves, then New England could meet the NERC operating requirement by maintaining approximately 700 MW of internal reserves
– Need to shed 700 MW of load within 10 minutes
• This level of internal reserves is also consistent with the NPCC requirement for spinning reserves (50% of the largest source contingency)
15
Questions?