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c i f i c a DIgSILENT Pacific P Power system engineering and software T N Emerging conventional generation E performance issues in a changing grid L Jaleel Mesbah and Tony Bertes I Technical Seminar PowerFactory 2020 S 14 February

  1. c i f i c a DIgSILENT Pacific P Power system engineering and software T N Emerging conventional generation E performance issues in a changing grid L Jaleel Mesbah and Tony Bertes I Technical Seminar PowerFactory 2020 S 14 February and 19 February 2020 g I D

  2. c i f i c a P Overview T • Motivation N • Transient and small signal stability background • Case studies: E - Generator performance during a recent system frequency event L - Increased VRE generation on small signal stability - Low inertia generator transient stability I S • Findings g 2 I D

  3. c i f i c a P Motivation T • A changing grid – frequency and severity: N - System frequency response to disturbances - Weather events and severe disturbances E - System load and generation profile L • Conventional generators still have a role to play in the grid I • Their performance has to be considered S g 3 I D

  4. c i f i c a P Synchronous generator dynamics Te T Prime N Shaft Generator Grid Mover E w Tm L • Tm = mechanical torque • Te = electrical torque 2𝐼 𝑒𝜕 I 𝑒𝑢 = 𝑈𝑛 − 𝑈𝑓 w = rotational speed • S • H = inertia g 4 I D

  5. c i f i c a P Synchronous generator stability • Transient stability primarily concerned with immediate effects of large T signal disturbances on power system synchronism • Following a disturbance, the generator speed and Pe will vary around its operating point, defined by the “swing equation” N E L • Small signal stability is defined by the ability of a power system to maintain synchronism under small disturbances (or perturbations) I S • Useful to decompose electrical torque into: • Damping torque g • Synchronising torque 5 I D

  6. c i f i c a P Effect of synchronising torques T N E L I S g 6 I D

  7. c i f i c a P Effect of damping torques T N E L I S g 7 I D

  8. c i f i c a P Key synchronous generator components T • Generator inertia • Changes acceleration rate and frequency of oscillations N • Automatic Voltage Regulator (AVR) • Controls generator voltage by changing excitation • Improves transient stability by increasing synchronising torque E • Can degrade small signal stability by reducing damping torque • Power System Stabiliser (PSS) L • Controls damping by applying bias signal to AVR • Improves small signal stability by increasing damping torque I • Uses power, speed or frequency measurements S • Do not respond to undesired stimuli • Do not overly impact voltage control g 8 I D

  9. c i f i c a P Case study: legacy PSS performance T • Generator performance during system event • Analysis of behaviour during event N • Analysis of PSS damping performance • Potential solutions E L I S g 9 I D

  10. c i f i c a P Performance during event T • Lightning event causes interconnector tripping and islanding N • Major frequency disturbance and load E shedding • Lightly damped active L power oscillations I S g 10 I D

  11. c i f i c a P Model performance assessment T • Simulation using model of generating system revealed similar performance N • PSS output saturates at negative limit during event E • Large negative bias applied • PSS not available for L damping • Dual input PSS (PSS3B) I with speed and power S inputs g 11 I D

  12. c i f i c a P PSS performance analysis – normal conditions T • Stable, well damped N E L I S g 12 I D

  13. c i f i c a P PSS performance analysis – emulated under- frequency conditions T • Unstable, undamped oscillations N E L I S g 13 I D

  14. c i f i c a P PSS poor performance causes T N E • Very large speed gain L • No washout filter on speed signal I • Long overall washout filter time constant S • Likely frequency disturbance not considered at time of design g 14 I D

  15. c i f i c a P PSS solution 1 • Tune washout filter T N E L I S g 15 I D

  16. c i f i c a P PSS solution 2 • Tune washout filter and PSS gains T N E L I S g 16 I D

  17. c i f i c a P Case study: VRE impact on stability • Penetration of VRE is expected to have an impact because: T • Reduction in system inertia N • Retirement of coal-fired generators – Hazelwood, Liddell?, ... E • Reduction in system strength • Increase in inverter-based generation L • Inverter-based resources exacerbate system strength issues I • Faster controller action in the grid S • Need to comply with the NER which has high performance-based metrics • In a weak grid (low system strength, low inertia) we see instability associated with fast acting controls and voltage instability (e.g. West Murray Zone) g 17 I D

  18. c i f i c a P Case study: VRE impact on stability T • Case study: 39 bus “New England” system N • Total generation dispatched of 6.1 GW (100% conventional) E • Available system inertia of ~4.58s L • Singe largest generator excluding the interconnection to rest of USA is 1,000 MVA I S g 18 I D

  19. c i f i c a P Test system T N E L I S g 19 I D

  20. c i f i c a P Test system – VRE added T • Retired generators G05 (300MVA) and G07 (700MVA) N • Replaced with a WTG (660 MVA) and PV plant (550 MVA) E – standard dynamic models also included L • System inertia reduces from I 4.58s to 4.29s S g 20 I D

  21. c i f i c a P Test system – VRE added T N E L I S g 21 I D

  22. c i f i c a P Test system – study of mode 84 T • One mode selected: -0.64 + j1.68 (frequency of 0.27 Hz) N G09 (nuclear plant) E Interconnection to L Rest of USA I S g 22 I D

  23. c i f i c a P Test system – retune of G09 PSS T N E L I S g 23 I D

  24. c i f i c a P Case study: Reduction in inertia T • The aggregated system inertia can be calculated in MW.s N � � ��� ��� E • Smaller values of H lead to higher RoCoF which causes rapid changes in system frequency and less stable behaviour L • Load shedding • Cascade tripping I • System collapse S g 24 I D

  25. c i f i c a P Case study: Reduction in inertia T N E L I S g 25 I D

  26. c i f i c a P Case study: Reduction in inertia T • Using “New England” test case N • Effect of VRE on transient stability is analysed by looking at a distant fault on Line 02-03 E • Using base-case (no VRE, higher system inertia), CFCT for a 3ph SC on Line 02- 03 is found to be 240ms L • With the addition of VRE and retirement of two generators, CFCT for same fault is found to be 200ms I S • Reduction in CFCT of 16% g 26 I D

  27. c i f i c a P Case study: Reduction in inertia T • Case study B: N • Existing Power Station with four gas turbines, upgrades turbines to light-weight aero-derivatives with lower inertia E • Aero-derivative turbines have much faster start-up times (start to PMAX in 5mins), and are able to respond to market demands quicker than heavier duty OCGT L • Disadvantage is the reduction in turbine inertia will have an impact on the Station to ride through disturbances (compliance with GPS) I S • Study is performed analysing CFCT for a 3ph fault at the POC in a reduced network simulation g 27 I D

  28. c i f i c a P Impact on transient stability – CFCT in SMIB Units in service Comments Inertia (s) Total inertia CCT 1 Unit 1 upgraded, dispatched in isolation T 1.9 1.9 0.2 0.22 1 Unit 1 pre-upgrade, dispatched in isolation 2.6 2.6 Unit 1 = 1.9 N Unit 2 = 2.6 2 Unit 1 upgraded, Unit 2 pre-upgrade 2.25 0.1375 Unit 1 = 1.9 Unit 2 = 1.9 2 Unit 1 and Unit 2 upgraded 1.9 0.135 Unit 1 = 1.9 E Unit 2 = 1.9 3 Unit 1 and 2 upgraded, Unit 3 pre-upgrade Unit 3 = 2.6 2.133 0.1175 Unit 1 = 1.9 Unit 2 = 1.9 L 3 All upgraded Unit 3 = 1.9 1.9 0.1125 Unit 1 = 1.9 Unit 2 = 1.9 I Unit 3 = 1.9 S 4 Unit 1-3 Upgraded, Unit 4 pre-upgrade Unit 4 = 2.6 2.075 0.112 0.105 4 All upgraded Unit 1-4 = 1.925 1.9 g 28 I D

  29. c i f i c a P Findings Case Findings Recommendations T Legacy stabilisers on existing Set and forget! Do now: Re-tune stabilisers for conventional generators optimum performance (5.3.9 Design likely not appropriate for process?) N current network conditions Wait and do: Wait as legacy systems are phased out during AVR upgrades E Impact of VRE on small signal Shift in modes (not all are bad) Co-ordinated study and setting of stability controllers (and PSS’s) to improved Some inter-area modes may be damping L found to be less damped As above (re-tune PSS’s) Reduction of system inertia High RoCoF Synchronous condensers I S Reduction in CFCT Synthetic inertia Inertia response as an ancillary g service Braking resistor 29 I D

  30. c i f i c a P Final remarks T • Most of our conventional generators are ageing assets that need to be managed and considered as today’s grid is changing N • We need to consider the limits of legacy systems E • Performance of conventional generators could be optimised through a L coordinated approach as more VRE comes online I S g 30 I D

  31. c i f i c a P T N E L I DIgSILENT Pacific S Power system engineering and software g I D

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