welcome
play

Welcome SERTP 2013 4 th Quarter Meeting Annual Transmission - PowerPoint PPT Presentation

Jan 31, 2024 •333 likes •1.12k views

2013 SERTP Welcome SERTP 2013 4 th Quarter Meeting Annual Transmission Planning Summit & Assumptions Input Meeting 1 2013 SERTP The SERTP process is a transmission planning process. Please contact the respective transmission

  1. 2013 SERTP Welcome SERTP 2013 – 4 th Quarter Meeting “ Annual Transmission Planning Summit & Assumptions Input Meeting” 1

  2. 2013 SERTP The SERTP process is a transmission planning process. Please contact the respective transmission provider for questions related to real-time operations or OATT transmission service. 2

  3. 2013 SERTP Purposes & Goals of the Meeting  10 Year Transmission Expansion Plan • East • West  2013 Economic Planning Study Results  Preliminary 2014 Modeling Assumptions • Load Forecast • Generation Assumptions  Miscellaneous Updates  Upcoming 2014 SERTP Process 3

  4. 2013 SERTP Ten Year Expansion Plan 4

  5. 10 Year Expansion Plan Timeline Approximate Planning Time Line (Years 1 – 5) Discuss the preliminary Assess need for expansion plan with the additional new projects. SERTP Stakeholders and obtain input. Base cases updated Approximate target for completion of year 1 – 5 with most recent input assumptions. evaluation. May ay Apr pr Jun un Mar Mar Jan an Feb Begin re-evaluation of existing projects for timing and need. Coordination among SERTP Sponsors and SERC members.

  6. 10 Year Expansion Plan Timeline Approximate Planning Time Line (Years 6 – 10) Approximate target Base cases updated for completion of year 6 – 10 evaluation. with most recent data. Discuss 10 year expansion plan at Base cases updated with Assess need for the Summit. most recent data and additional new projects. begin reviewing 10 year expansion plan. Aug ug Sep ep Oct Oct Jun un Jul uly Nov No Dec ec Discuss previous or obtain Begin re-evaluation of Obtain input from additional SERTP stakeholder existing projects for stakeholders on input on expansion plan. timing and need. assumptions for next year’s expansion plan process. Coordination among SERTP Sponsors and SERC members.

  7. 2013 SERTP The projects described in this presentation represent the ten (10) year expansion plan. The expansion plan is periodically reviewed and may be revised due to changes in assumptions. This presentation does not represent a commitment to build for projects listed in the future. 7

  8. 2013 SERTP The in-service date of each project is June 1 st of the stated project year, unless otherwise specified. The need date of each project is the same as the in-service date, unless otherwise specified. 8

  9. 2013 SERTP 2013 Ten Year Expansion Plan EAST WEST 9

  10. 2013 SERTP Economic Planning Studies 10

  11. 2013 SERTP Five Economic Planning Studies  Southern to SCPSA Border • 500 MW (2015 Winter Peak)  Southern to SCE&G Border • 500 MW (2015 Winter Peak)  TVA Border to Southern • 1500 MW (2017 Spring Valley)  TVA Border to Southern • 1500 MW (2017 Summer Peak)  Southern to PJM • 1000 MW (2023 Summer Peak) 11

  12. 2013 SERTP Power Flow Cases Utilized  Study Years: 2015, 2017, 2023  Load Flow Cases: • 2013 Series Version 2A o Summer Peak o Shoulder o Winter Peak o Spring Valley 12

  13. 2013 SERTP Economic Planning Studies  Final Report Components: • Thermal Analysis o Contingency Analysis to identify constrained elements/contingency pairs • Interface Transfer Capability Impacts • Stability Impacts • Potential Solutions o Transmission Enhancements and Cost Estimates 13

  14. 2013 SERTP The following information depicts recommended enhancements for the proposed transfer levels above and beyond existing, firm commitments. Therefore, this information does not represent a commitment to proceed with the recommended enhancements nor implies that the recommended enhancements could be implemented by the study dates (2015, 2017, 2023). These potential solutions only address constraints identified within the SERTP Sponsors’ areas that are associated with the proposed transfers. Other Balancing Areas were not monitored which could result in additional limitations and required system enhancements. 14

  15. 2013 SERTP Southern to SCPSA Border 500 MW 15

  16. Southern to SCPSA Border 500 MW  Transfer Type: Generation to Load (2015 Winter Peak)  Source: Southern Generation  Sink: Uniform load scale in SCPSA Source Sink 16

  17. DUKE TVA 0.9% 0.4% 3.7% 12.4% SMEPA 74.3% 0.5% 8.4% 16.0% APC 2.3% GA ITS MPC 3.3% 1.1% Gulf 1.2% 0.0% 0.7% Source 0.5% PSEC Sink

  18. Southern to SCPSA Border 500 MW Transmission System Impacts  Thermal Constraints Identified: • One (1) 115 kV T.L. Total Cost (2013$) = $9,000,000 18

  19. Southern to SCPSA Border 500 MW Significant Constraints – Pass 0 Thermal Loading (%) Rating Limiting Elements Without With (MVA) Request Request Chatsworth – Coosawattee 115 kV TL 137 91.9 102.4 19

  20. Southern to SCPSA Border 500 MW Significant Constraints – Pass 0 GA ITS APC MPC Gulf 20

  21. Southern to SCPSA Border 500 MW Significant Constraints – Pass 0 (P1 (P1) ) Chatsworth tsworth – Coosa sawattee wattee 115 kV 21

  22. Southern to SCPSA Border 500 MW Projects Identified Item Proposed Enhancements Cost ($) Chatsworth – Coosawattee 115 kV T.L. P1 $9,000,000 - Reconductor approximately 12 miles of 336 ACSR 115 kV transmission line with 795 ACSR at 100°C. Total Cost (2013$) = $9,000,000 22

  23. 2013 SERTP Southern to SCE&G Border 500 MW 23

  24. Southern to SCE&G Border 500 MW  Transfer Type: Generation to Load (2015 Winter Peak)  Source: Southern Generation  Sink: Uniform load scale in SCE&G Source Sink 24

  25. DUKE TVA 0.9% 0.3% 2.6% 11.9% SMEPA 75.9% 0.5% 8.2% 16.6% APC 2.1% GA ITS MPC 3.3% 1.2% Gulf 1.2% 0.0% 0.7% Source 0.5% PSEC Sink

  26. Southern to SCE&G Border 500 MW Transmission System Impacts  Thermal Constraints Identified: • One (1) 115 kV T.L. Total Cost (2013$) = $9,000,000 26

  27. Southern to SCE&G Border 500 MW Significant Constraints – Pass 0 Thermal Loading (%) Rating Limiting Elements Without With (MVA) Request Request Chatsworth – Coosawattee 115 kV TL 137 91.9 102.4 27

  28. Southern to SCE&G Border 500 MW Significant Constraints – Pass 0 GA ITS APC MPC Gulf 28

  29. Southern to SCE&G Border 500 MW Significant Constraints – Pass 0 (P1 (P1) ) Chatsworth tsworth – Coosa sawattee wattee 115 kV 29

  30. Southern to SCE&G Border 500 MW Projects Identified Item Proposed Enhancements Cost ($) Chatsworth – Coosawattee 115 kV T.L. P1 $9,000,000 - Reconductor approximately 12 miles of 336 ACSR 115 kV transmission line with 795 ACSR at 100°C. Total Cost (2013$) = $9,000,000 30

  31. 2013 SERTP TVA Border to Southern 1500 MW (Spring Valley) 31

  32. TVA Border to Southern 1500 MW (Spring Valley)  Transfer Type: Load to Generation (2017 Spring Valley)  Source: Uniform load scale in TVA  Sink: Southern Generation Source Sink 32

  33. DUKE TVA 2.7% 0.3% 34.7% SMEPA 29.6% 20.1% 13.1% 0.7% 4.1% 5.8% APC GA ITS MPC 4.0% 0.0% Gulf 1.4% 1.8% 0.3% Source 0.1% PSEC Sink

  34. TVA Border to Southern 1500 MW (Spring Valley) Transmission System Impacts  Thermal Constraints Identified: • None Total Cost (2013$) = $0 34

  35. 2013 SERTP TVA Border to Southern 1500 MW (Summer Peak) 35

  36. TVA Border to Southern 1500 MW (Summer Peak)  Transfer Type: Load to Generation (2017 Summer Peak)  Source: Uniform load scale in TVA  Sink: Southern Generation Source Sink 36

  37. DUKE TVA 2.5% 0.2% 35.8% SMEPA 28.8% 20.8% 12.4% 0.6% 5.1% 6.7% APC GA ITS MPC 4.9% 0.1% Gulf 1.1% 1.7% 0.5% Source 0.1% PSEC Sink

  38. TVA Border to Southern 1500 MW (Summer Peak) Transmission System Impacts  Thermal Constraints Identified: • One (1) 500 kV T.L. • Five (5) 230 kV T.L. • Two (2) 161 kV T.L. Total Cost (2013$) = $137,900,000 38

  39. TVA Border to Southern 1500 MW (Summer Peak) Significant Constraints – Pass 0 Thermal Loading (%) Rating Limiting Elements Without With (MVA) Request Request Conasauga – Bradley TN 500 kV TL 104.2 (1) 2598 88.0 South Hall – Candler 230 kV TL 509 93.8 103.0 Pinson – Oostanaula 230 kV TL 101.2 664 85.5 Bio – Vanna 230 kV TL 433 96.0 101.1 Lexington – Russell 230 kV TL 100.4 596 95.1 (1) The limiting element of this tie-line constraint is located within TVA 39

  40. TVA Border to Southern 1500 MW (Summer Peak) Significant Constraints – Pass 0 GA ITS APC MPC Gulf 40

  41. TVA Border to Southern 1500 MW (Summer Peak) Significant Constraints – Pass 0 S. Hall – Candler r 230 kV Bio – Vanna 230 kV Pinso son – Oosta stanaula 230 kV Russ ssell – Lexington ton 230kV 41

  42. TVA Border to Southern 1500 MW (Summer Peak) Proposed Enhancements – Pass 1 (P1 (P1) ) Russ ssel Dam m – Athe thena 230kV 42

  43. TVA Border to Southern 1500 MW (Summer Peak) Significant Constraints – Pass 1 Thermal Loading (%) Rating Limiting Elements Without With (MVA) Request Request Fayette – Gorgas 161 kV TL 103.2 (1) 126.8 193 Attalla – Albertville 161 kV TL 193 96.8 122.7 Clay – Argo 230 kV TL 108.7 602 87.9 Leeds TS – Argo 230 kV TL 602 84.5 105.3 (1) A current operating procedure is sufficient to alleviate this identified constraint without the addition of the proposed transfer. However, the additional transfer exacerbates the loading on this transmission facility such that the operating procedure becomes insufficient. 43

Recommend

More recommend