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SCHEDULE 2 - VAR SUPPORT

SCHEDULE 2 - VAR SUPPORT. NEPOOL Tariff Committee Meeting July 19, 2001 - Status Report Richard W. Burke - ISO New England. SCHEDULE 2 - VAR SUPPORT. Amendment Setting Non - $0 Capacity Cost Filed At FERC May 29, 2001

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SCHEDULE 2 - VAR SUPPORT

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  1. SCHEDULE 2 - VAR SUPPORT • NEPOOL Tariff Committee Meeting • July 19, 2001 - Status Report • Richard W. Burke - ISO New England

  2. SCHEDULE 2 - VAR SUPPORT • Amendment Setting Non - $0 Capacity Cost Filed At FERC May 29, 2001 • FERC Order Dated June 28, 2001 Accepts Submittal- Sets August 1, 2001 As Effective Date • Template Drafted To Capture Qualified Generators Eligible For Compensation And To Determine The Qualified VARS Of Each

  3. SCHEDULE 2 - VAR SUPPORT • Qualified Generators Listed Are Those In The Market System (EMS) • Generators’ Summer Seasonal Capability Values Are Determined During The Forecast Peak Adjusted Reference Load Period (Typically August) • Normal Operating Reactive Capability Lagging MVARs From NX-12D Pt. 13 = (QSCC)

  4. SCHEDULE 2 - VAR SUPPORT • General Calculation Methodology • GSU Losses Calculated By Modeling An Equivalent Circuit Using Per Unit Values • From NX-9B Form Convert X% to X p.u. As X%/100 (NOTE: Per Unit Value = Actual Value/Base Value)

  5. SCHEDULE 2 - VAR SUPPORT • Calculate Generator’s Apparent Power = S (MVA) • Where P = (MW) (SCC); Q = (MVAr) (SCC) • S= [(P)2 + (Q)2]1/2 • Calculate Generator’s Power Factor = Cos. ø • Cos. Ø = P/S

  6. SCHEDULE 2 - VAR SUPPORT • Solve For Generator Current = IG (kA) • Where P = (MW) (SCC); VT = Generator Terminal Voltage As Documented On NX-9B (kV) • IG = P/[(3)1/2* VT * Cos. Ø]

  7. SCHEDULE 2 - VAR SUPPORT • Determine Ibase On Generator Ratings (kA) • Where Sbase = 100 MVA; Vbase = VT (kV) • Ibase = Sbase/[(3)1/2* Vbase] • Convert IG To Per Unit As: Ip.u. = IG/ Ibase

  8. SCHEDULE 2 - VAR SUPPORT • Determine Qlosses transformer p.u. (Per Unit) • Where GSU X% = Generator Step Up Transformer Impedance Data (%) (100 MVA Base) As Documented on NX-9B (%) • Xp.u. = X%/100 • Qlosses transformer p.u = (Ip.u.)2* (Xp.u.)

  9. SCHEDULE 2 - VAR SUPPORT • Actual GSU Losses Are: Qactual (MVAr) • Qactual losses transformer = Qlosses transformer p.u. * Sbase • Qactual = Qp.u.* 100MVA • Determine Qualified Generator MVArs • Qqualified MVAr = QSCC - Qactual

  10. SCHEDULE 2 - VAR SUPPORT • Issues • NX-12D Forms From EMS Generators - Rare • < 13.5% of EMS Units Have NX-12D Forms On File • NX-9B Database Sparsely Populated (GSU) • Many Forms Are For New Units That Are Not Yet In The EMS • <2.4% of EMS Units Have GSU Data In ISO Database • Data Required To Determine VAR Capability • < 1.7% (EMS Data/NX12 Data/NX-9B Data

  11. SCHEDULE 2 - VAR SUPPORT • Solution • Mailing To All EMS Generator Owners To Request: • Updated NX-12D Form With Point 13 Data Supplied • Updated NX-9B Form Attached to NX-12D Form With Each Generator’s GSU (Multiple plant/CC Units) Reactance Data Supplied And A Succinct Identification To Match The Gen. Unit With Its GSU • Those Owners Not Supplying Timely Data Will Have Their Payments Delayed

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