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SPP Sub-Regional Planning Meeting Local Area 2 Overland Park, KS August 3, 2010

SPP Sub-Regional Planning Meeting Local Area 2 Overland Park, KS August 3, 2010. Electric Systems Planning. Agenda. Company Overview Project Overview System Data. Company Overview. Chartered by the City of Springfield, MO.

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SPP Sub-Regional Planning Meeting Local Area 2 Overland Park, KS August 3, 2010

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  1. SPP Sub-Regional Planning MeetingLocal Area 2Overland Park, KSAugust 3, 2010 Electric Systems Planning

  2. Agenda • Company Overview • Project Overview • System Data

  3. Company Overview

  4. Chartered by the City of Springfield, MO. • Community-owned utility providing electricity, natural gas, water, telecommunications and transit services. • CU served 108,819 electric customers in 2009.

  5. Board of Public Utilities • CU is governed by an 11-member Board of Public Utilities, nine who are customers inside the city and two who are customers outside the city. • Board members are appointed by the Springfield City Council to serve 3-year terms. • The Board makes policy decisions for CU and appoints the General Manager.

  6. CU Citizens’ Advisory Council • This cross-section of community leaders acts as a liaison between the community and the Board and management staff of City Utilities. • The Council also acts as a representative for utility customers, encouraging participation in the utility’s decision-making process and bringing recommendations to the Board of Public Utilities to better serve our customers. • Meetings are held monthly.

  7. Quick Facts • Facts and figures about City Utilities and the electricity, natural gas, water and transit systems are available to the public. • http://www.cityutilities.net/about/about.htm

  8. Electric Statistics, 2009

  9. Interconnection To Morgan – Brookline – Flint Creek 345kV

  10. Springfield Area HV

  11. Area Communities

  12. Service Area

  13. Project Overview • (2010) Completed replacing the conductor in the Norton to Neergard 69 kV line with 477 kcmil ACSS/TW on May 28. • (2010) For interconnecting the SWPS #2 275 MW net source, additions in switch station and transformer are scheduled for completion October 1. • (2010) Replace switches and metering CTs in Brookline – Junction 161 kV terminals by November prior to June 2013 need date.

  14. (Expediting to 2014) Add Twin Oaks 30 MVAR cap bank deferring 2 line projects. • (2014 deferred to 2018) Replace James River to Twin Oaks 69 kV conductor with 180 MVA capacity conductor, e.g. 762.8 kcmil ACSS/TW. • (2015 deferred to 2018) Replace the conductor in the Kickapoo to Sunset 69 kV line with 175 MVA capacity conductor, e.g. 762.8 kcmil ACSS/TW.

  15. (2016) Replace the conductor in the James River to South Highway 65 69 kV line with 150 MVA capacity conductor is required, e.g. 762.8 kcmil ACSS/TW. • (2017) Replacing the conductor in the South Highway 65 (S65) to Sunset 69 kV line with 150 MVA capacity conductor is needed, e.g. 762.8 kcmil ACSS/TW. • These 2 replacements are to mitigate the outage of a 69 kV double circuit, JRPS to Seminole and JRPS to Twin Oaks circuits.

  16. Reporting of Electric Systems Studies • City Utilities’ Master Plan for Electric Transmission provides the details of the necessary planned improvements through the planning horizon. • Annual updates of the Master Plan are completed. • This information is not posted for security. • Information is also summarized in FERC Form 715 and filed annually.

  17. Transmission System

  18. Northwestern Area

  19. Northeastern Area

  20. Southeastern Area

  21. Short-Term Transmission Evaluations • Brookline 345/161 kV Substation auto-transformers, 1 each owned by CU and AECI, projected to be overloaded. • Prior to SPP recognizing CU’s SWPS#2 generator addition. • During evaluation of Chouteau – Blackberry 345 kV interconnection. • In later SPP TSR initial studies.

  22. Brookline Review By CU 2009, 1 XF Out • SPP 2009 STEP 14SP B1 Scenario 1 model used. • For each local modeled CA, interchange, generation & load = 0, remote generation adjusted for int. • XFMR usage: CU = 6.3%, SWPA = -14.9%, totaling -8.6% for SWPA BA. • XFMR usage: EMDE = 23.8%, AECI = 36.8%, & Others = 48%.

  23. Brookline – Summit 345 kV & XF addition. • Chesapeake Tap 345 kV & XF. • Monett 345/161 kV. • Brookline – Branson 345 kV & XF in lieu of Monett - Branson. • Morgan 345/161 kV 500 MVA north of CU. • Brookline – Tauria (N Branson) 345 kV & 500 MVA XF with opt SWPA 161 KV tie. • Brookline – Tauria 345 kV & 500 MVA XF. • Brookline Mitigations Evaluated By SPP

  24. Brookline – Summit 345 kV & XF addition, 78.3%. • Brookline – Tauria (N Branson) 345 kV & 500 MVA XF with opt SWPA 161 KV tie, 77.2%. • Brookline – Tauria 345 kV & 500 MVA XF, 78.9%. • Morgan 345/161 kV 500MVA north of CU, 89.0%. • Chesapeake Tap 345 kV & XF, 89.9%. • Brookline – Branson 345 kV & XF in lieu of Monett – Branson, 91.2%. • Monett 345/161 kV, 97.0%. • Brookline Mitigations Ranked By SPP With Brookline 345/161 kV N-1 loading • Rankings do not take into account usage by others.

  25. SPP-2009-AGP2-AFS-4 Dated July 23 With Brookline 345/161 kV Max Loading • 99.3% in 11SP while using AECI’s Brookline operating guide. • 106.8% in 12SP. • 97.3% in 12WP. • 95.3% in 21SP. • Upgrades include AEPW Shipe Road – East Rogers – Osage Creek 345kV & Osage Creek 345/161kV. • No other upgrades can be constructed to mitigate Brookline overload in near term.

  26. SPP-2010-AGP1-AFS-1 Dated July 30 With Brookline 345/161 kV Max Loading • 110.5% in 12SP. • 111.1% in 12WP. • 102.0% in 21SP. • Upgrades include AEPW Shipe Road – East Rogers – Osage Creek 345kV. Add Osage Creek & Centerton 345/161kV. • Upgrades include KCPL LaCygne - Franks 345kV.

  27. Ongoing Transmission Evaluations • Brookline 345/161 kV mitigation options near Branson Missouri. • Southwest Power Station – Junction 161 kV line in western area to mitigate Brookline – Junction 161 kV overload. • Mentor – McCartney 161 kV line in eastern area to mitigate overloads of Mill 161/69 kV Substation and 69 kV lines.

  28. System Data • Load Forecasting Methodology • Burns & McDonnell provides energy and demand forecasting services. • Econometric models are used to forecast trends. • Projections by customer class are developed using system energy, demand and weather data. • Weather uncertainty analyses are conducted using maximum and minimum cooling degree days in determining residential energy sales. • The system load is summer peaking with a significant amount of air conditioning load.

  29. Coincident Demand Forecast

  30. Transmission Bus Coincident Load Projections • Real and reactive historical demand data by distribution feeder at system peak is used. • Substation demands are adjusted to equal the projected annual coincident system peak at 99° F while using substation growth factors. • Distribution reactive compensation is accounted for in determining future reactive loads. • Calculated reactive losses of each distribution substation transformer including proposed units are included in primary load forecasts.

  31. Transmission Reliability Criteria • Reliability criteria used is NERC Transmission Planning Standards TPL-001 through TPL-004 including Table I. • SPP Criteria used including Criteria 3 & 12. • Voltage limits are +/-5% of nominal voltage under normal operating conditions. • Voltage limits are +5/-10% of nominal voltage under first contingency operating conditions defined in Table I.

  32. To meet voltage requirements, auto-transformer no-load taps are changed before and after the summer operating period. • Sufficient reactive capacity shall be planned to maintain voltages within the defined operating limits.

  33. Under normal operating conditions, line, transformer and equipment loadings shall be within normal operating limits. • During N-1 and more probable outages, these facility loadings shall be within emergency ratings. • No loss of customer’s electrical service shall occur except as noted in Table I of NERC Transmission Planning Standards.

  34. All other Transmission Owners’ voltage limits are monitored and adhered to. • Facilities are planned such that the interconnected system’s voltage, thermal and stability limits are not exceeded during the operating contingencies throughout the planning horizon. • Information is summarized in FERC Form 715 and filed annually.

  35. Transmission Planning Participation • SPP Transmission Expansion Plan development per Attachment O of the Open Access Transmission Tariff. • SPP Coordinated Generation Interconnection Procedures and Agreements per Att. V. • SPP Aggregate Transmission Service Studies per Att. Z. • Local area community and utility meetings to coordinate planning, interconnection, operations, and maintenance issues.

  36. http://www.cityutilities.net/ Posted Information

  37. Questions? John Chamberlin, PEJohn.Chamberlin@cityutilities.net417-831-8760

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