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Effect of generation loss and Frequency Response Characteristics (FRC) on tie-line flow to Southern Region under various scenarios and Target setting for FRC and introduction of secondary control in Indian power system. Assumptions: Initial frequency: 50.00 Hz

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  1. Effect of generation loss and Frequency Response Characteristics (FRC) on tie-line flow to Southern Region under various scenarios and Target setting for FRC and introduction of secondary control in Indian power system

  2. Assumptions: • Initial frequency: 50.00 Hz • Capacity on bar in NEW Grid • 93500/0.85 = say 110000 MW • Capacity on bar in SR grid • 26500/0.85 = 31200 MW say • Frequency Response of load • 3% of load per Hz change uniform • Governor droop • 5% wherever primary response is there viz. 40% load per Hz • Losses ignored for simplicity NEW Grid Generation: 93500 MW Load: 90000 MW Export to SR: 3500 MW 3500 MW Generation: 26500 MW Load: 30000 MW Import from NEW: 3500 MW SR Grid

  3. Effect of 1000 MW generation loss on tie-line flow to SR and frequency under various scenarios

  4. Observations to note • Primary response is important on account of • Frequency stabilization post disturbance (case A1 & A2 vs others) • Minimize Under Frequency Relay (UFR) operations • Frequency stabilization in case of islanding of systems • Primary response cannot and does not • Influence tie-line loading under contingencies (A1/B1, A2/ B2); • hourly boundary flow change problem will remain; load-shedding will gradually get replaced by economy interchange over certain hours of the day as prevailing in systems worldwide. • Automatic Generation Control (AGC), if available, would bring down the tie-line loading to schedule in 8-10 minutes. • Skewed primary response can deteriorate tie-line loading • Case C2 and D1

  5. Frequency Bias, B • Area Control Error (ACE) equation ACE = (NIA- NIS) – 10B (FA - FS) - IME • Where NIA is Actual Net Interchange • NIS is Scheduled Net Interchange • Bis Control Area Bias • FA is Actual Frequency • FS is Scheduled Frequency • IME is Interchange (tie line) Metering Error B should ideally be greater than or equal to ß, the control area frequency response (better to have slight over-correction). traditionally 1% of peak load/generation per 0.1 Hz

  6. What does 1% of peak load/generation per 0.1 Hz translate to? • Governor droop setting is typically 5% which translates to 100% load change over 2.5 Hz frequency variation viz. 40% per Hz or 4% per 0.1 Hz. • Bias B of 1% per 0.1 Hz translates to 25% of ideal response of 4% per 0.1 Hz.

  7. Even for the ENTSOE system with mean generation of the order of 306 GW ,the overall FRC is of the order of 26000 MW/Hz or 20-25 % of ideal response. So ideal response appears to be a myth!!

  8. Reasons for decline in frequency response • Steam turbine generators operating on “sliding pressure” or “boiler-follower” control and/or with “valves wide-open” (VWO) operation. • Blocked governors on nuclear units for licensing reasons. • Less heavy manufacturing in North America (proportionally fewer large motor loads and a reduction in “load rejection”). • Variable-speed drives on motors that do not provide the traditional “load rejection”. • A larger proportion of combined cycle units on the system • In the past, many Control Areas carried full reserves for their individual largest contingency and some for multiple contingencies. De-regulation and competitive pressures have ended both of these practices. NERC: Frequency Response white paper

  9. Setting Target Frequency Response Obligations NERC Reliability Standard Attachment A of BAL-003-1: Frequency Response and Bias Setting Standard

  10. Setting Target Frequency Response Obligations Each control area target Frequency Response Obligation is worked out as NERC Reliability Standard Attachment A of BAL-003-1: Frequency Response and Bias Setting Standard

  11. FRC Target in the Indian context • Minimum frequency: 49.8 Hz • First Stage of Under Frequency: 49.2 Hz • Largest contingency: 4000 MW UMPP • FRC > 4000 MW/0.6 Hz or 6666 MW/Hz if UFRs are not to operate • Assuming 25% margin this works out to • 8333 MW/Hz • Load response would be adequate only if All India load would reach 280 GW • Target would double if minimum frequency touches 49.5 Hz in normal course • 8333 MW/Hz might be only 16-17% of ideal response of the order of 50,000 MW/Hz.

  12. Secondary Control • Secondary control • Tight control on deviations…….CERC is moving in this direction through pricing deviations and zero crossing • Area Control Error (ACE) could be introduced once FRC computations are on a sound footing and publicized so that Bias B can be fixed for each control area • Automatic Generation Control (AGC) could be introduced in phases • Outer loop operating from RLDCs to ISGS for frequency control and inter-regional tie line control • Inner loop operating from SLDCs to intra state generating stations for reducing control area ACE.

  13. Thank you

  14. Computations for tie-line flows under various scenarios indicated above

  15. Case A1: 1000 MW generation loss in NEW Grid and no primary response in the entire grid; only 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = NIL; SR grid primary response = NIL; Combined primary response = NIL • Stabilized frequency = 50 Hz-(1000/3600) Hz = 49.7222 Hz • Post disturbance • Gen in NEW Grid = 93500-1000 = 92500 MW • Load in NEW Grid = 90000 MW-(0.2778 x 2700) MW = 89250 MW • Export to SR Grid = 92500 MW -89250 MW = 3250 MW • Gen in SR Grid = 26500 MW (no change) • Load in SR Grid = 30000-(0.2778 x 900) = 29750 MW • Import from NEW Grid = 29750 MW-26500 MW = 3250 MW • Thus tie-line flow reduces from 3500 MW to 3250 MW. Viz. 250 MW

  16. Case A2: 1000 MW generation loss in SR Grid and no primary response in the entire grid; only 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = NIL; SR grid primary response = NIL; Combined primary response = NIL • Stabilized frequency = 50 Hz-(1000/3600) Hz = 49.7222 Hz • Post disturbance • Gen in NEW Grid = 93500 (no change) • Load in NEW Grid = 90000 MW-(0.2778 x 2700) MW = 89250 MW • Export to SR Grid = 93500 MW -89250 MW = 4250 MW • Gen in SR Grid = 26500 MW-1000 MW = 25500 MW • Load in SR Grid = 30000-(0.2778 x 900) = 29750 MW • Import from NEW Grid = 29750 MW-25500 MW = 4250 MW • Thus tie-line flow increases from 3500 MW to 4250 MW viz. 750 MW

  17. Case B1: 1000 MW generation loss in NEW Grid and 50% primary response in the entire grid; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 109000 MW capacity on bar after tripping of 1000 MW x 0.40 x 0.50 = 21800 MW/Hz ; SR grid primary response = 31200 MW capacity on bar x 0.40 x 0.50= 6240 MW/Hz; Combined primary response = 28040 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 28040) Hz = 49.9684 Hz • Post disturbance • Gen in NEW Grid = 93500-1000 + (0.0316 x 21800) = 93190 MW • Load in NEW Grid = 90000 MW-(0.0316 x 2700) MW = 89915 MW • Export to SR Grid = 93190 MW -89915 MW = 3275 MW • Gen in SR Grid = 26500 MW + (0.0316 x 6240) = 26697 MW • Load in SR Grid = 30000-(0.0316 x 900) = 29972 MW • Import from NEW Grid = 29972 MW-26697 MW = 3275 MW • Thus tie-line flow reduces from 3500 MW to 3275 MW. Viz. 250 MW

  18. Case B2: 1000 MW generation loss in SR Grid and 50% primary response in the entire grid; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 110000 MW capacity on bar x 0.40 x 0.50 = 22000 MW/Hz ; SR grid primary response = 30200 MW capacity on bar after tripping of 1000 MW x 0.40 x 0.50= 6040 MW/Hz; Combined primary response = 28040 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 28040) Hz = 49.9684 Hz • Post disturbance • Gen in NEW Grid = 93500 + (0.0316 x 22000) = 94195 MW • Load in NEW Grid = 90000 MW-(0.0316 x 2700) MW = 89915 MW • Export to SR Grid = 94195 MW -89915 MW = 4280 MW • Gen in SR Grid = 26500 MW-1000 + (0.0316 x 6040) = 25691 MW • Load in SR Grid = 30000-(0.0316 x 900) = 29972 MW • Import from NEW Grid = 29972 MW-25691 MW = 4281 MW • Thus tie-line flow increases from 3500 MW to 4280 MW. Viz. 780 MW

  19. Case C1: 1000 MW generation loss in NEW Grid and 50% primary response in NEW Grid only; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 109000 MW capacity on bar after tripping of 1000 MW x 0.40 x 0.50 = 21800 MW/Hz ; SR grid primary response = 0 MW/Hz; Combined primary response = 21800 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 21800) Hz = 49.9606 Hz • Post disturbance • Gen in NEW Grid = 93500-1000 + (0.0394 x 21800) = 93359 MW • Load in NEW Grid = 90000 MW-(0.0394 x 2700) MW = 89894 MW • Export to SR Grid = 93359 MW -89894 MW = 3465 MW • Gen in SR Grid = 26500 MW (no change) • Load in SR Grid = 30000-(0.0394 x 900) = 29965 MW • Import from NEW Grid = 29965 MW-26500 MW = 3465 MW • Thus tie-line flow reduces from 3500 MW to 3465 MW. Viz. 35 MW

  20. Case C2: 1000 MW generation loss in SR Grid and 50% primary response in NEW Grid only; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 110000 MW capacity on bar x 0.40 x 0.50 = 22000 MW/Hz ; SR grid primary response = 0 MW/Hz; Combined primary response = 21800 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 22000) Hz = 49.9609 Hz • Post disturbance • Gen in NEW Grid = 93500 + (0.0391 x 22000) = 94360 MW • Load in NEW Grid = 90000 MW-(0.0391 x 2700) MW = 89895 MW • Export to SR Grid = 94360 MW -89895 MW = 4465 MW • Gen in SR Grid = 26500 MW-1000 MW = 25500 MW • Load in SR Grid = 30000-(0.0391 x 900) = 29965 MW • Import from NEW Grid = 29965 MW-26500 MW = 4465 MW • Thus tie-line flow increases from 3500 MW to 4465 MW. Viz. 965 MW

  21. Case D1: 1000 MW generation loss in NEW Grid and 50% primary response in SR Grid only; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 0 MW/Hz ; SR grid primary response = 31200 MW capacity on bar x 0.40 x 0.50 = 6240 MW/Hz; Combined primary response = 6240 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 6240) Hz = 49.8984 Hz • Post disturbance • Gen in NEW Grid = 93500-1000 = 92500 MW • Load in NEW Grid = 90000 MW-(0.1016 x 2700) MW = 89726 MW • Export to SR Grid = 92500 MW -89726 MW = 2774 MW • Gen in SR Grid = 26500 MW + (0.1016 x 6240) = 27134 MW • Load in SR Grid = 30000-(0.1016 x 900) = 29909 MW • Import from NEW Grid = 29909 MW-27134 MW = 2775 MW • Thus tie-line flow reduces from 3500 MW to 2775 MW. Viz. 725 MW

  22. Case D2: 1000 MW generation loss in SR Grid and 50% primary response in SR Grid only; 3% per Hz load response • Load response of NEW Grid: 0.03*90000 MW= 2700 MW/Hz; Load response of SR Grid= 0.03*30000 MW = 900 MW/Hz; Combined load response= 3600 MW/Hz • Primary response NEW grid = 0 MW/Hz ; SR grid primary response = 30200 MW capacity on bar after tripping of 1000 MW x 0.40 x 0.50 = 6040 MW/Hz; Combined primary response = 6040 MW/Hz • Stabilized frequency = 50 Hz-(1000/(3600 + 6040) Hz = 49.8963 Hz • Post disturbance • Gen in NEW Grid = 93500 MW (no change) • Load in NEW Grid = 90000 MW-(0.1037 x 2700) MW = 89720 MW • Export to SR Grid = 93500 MW -89720 MW = 3780 MW • Gen in SR Grid = 26500 MW -1000 + (0.1037 x 6240) = 26126 MW • Load in SR Grid = 30000-(0.1037 x 900) = 29906 MW • Import from NEW Grid = 29906 MW-26126 MW = 3780 MW • Thus tie-line flow increases from 3500 MW to 3780 MW. Viz. 280 MW

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