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WTS Scheduling 101

WTS Scheduling 101

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WTS Scheduling 101

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  1. WTS Scheduling 101

  2. Agenda 9:00am Welcome & Introduction Brenda Ambrosi 9:30am TTC/ATC Stephen Tran • WECC Path Ratings • WECC Operating Transfer Capability • Total Transfer Capability • Firm TTC • Transmission Reliability Margin • Available Transfer Capability Transmission Services 10:15am BREAK 10:30am Long-Term Transmission Service Stephen Tran • Business Practice Section 15 (LTPTP) • Procedures and Timelines • Business Practice Section 16 (Rollover Rights) NOON LUNCH 1:00pm Scheduling Tools Raj Hundal 1:15pm OASIS Raj Hundal 1:30pm Reserving Transmission Raj Hundal 2:30pm BREAK 2:45pm Scheduling Energy Raj Hundal 3:15pm Interruptions and Curtailments Raj Hundal 3:30pm Loss Compensation Service Raj Hundal 3:45pm Settlement and Billing Raj Hundal 3:55pm Wrap up and Thank You Brenda Ambrosi Scheduling 101

  3. Introduction Scheduling 101

  4. BCTC • A provincial Crown Corporation that was created in 2003 • BCTC is separate from BC Hydro, and has its own Board of Directors • Responsibilities: • plan, operate, maintain, and manage the electrical transmission system in BC • provide open, non-discriminatory access to transmission capacity by administering the Open Access Transmission Tariff (OATT) • provide interconnection services • Regulated by the British Columbia Utilities Commission (BCUC) Scheduling 101

  5. Western Interconnection • The Western Interconnection is a synchronous connection of interconnected utilities (operated as Control Areas*) with the sole mandate of providing reliable service • The Western Electricity Coordinating Council (WECC) is the body charged with ensuring this reliable service is provided * Control Area is defined as an electrical system bounded by interconnection metering and telemetry. The Control Area controls its generation to maintain its interchange schedule while regulating interconnection frequency. Scheduling 101

  6. Interties - Neighboring Control Areas • The BCTC Control Area interties with the Alberta Electric System Operator (AESO) to the East • The BCTC Control Area interties with Bonneville Power Administration (BPAT) to the south Scheduling 101

  7. Organization Chart Scheduling 101

  8. Market Operations • Market Operations is the department within BCTC that provides: • Transmission Services: • Network Integration Transmission Services (multiple POD/POR) • Point-to-Point (single POD/POR) • Interconnection Services: • Interconnection Studies • Interconnection Requirements • Construction & Interconnection Scheduling 101

  9. What is the OATT? • OATT based on physical capacity reservations – contrasted with pool designs where service priority is based on merit dispatch • Priority based on nature of service, and the “first come, first served” principle • OATT defines the rates, and terms and conditions of transmission service offered to eligible customers • Open access allows any eligible transmission customer to use the grid to move power from within, out of, or across BC • Open access facilitates opportunities for new and emerging energy market participants • OATT is found on website at http://www.bctc.com/regulatory/tariff/open_access_tariff.htm Scheduling 101

  10. What is a Business Practice? • Business Practices provide clarity as to how the Tariff rules will be implemented • NOT new terms and conditions • Ensure that you subscribe to BCTC’s Business Practices at http://www.bctc.com/transmission_scheduling/business_practices/ to receive automatic notification of updates Scheduling 101

  11. Customer Registration Scheduling 101

  12. Registration • Section 1 of BCTC’s Business Practices sets out the Customer Registration Procedures, which is found at http://www.bctc.com/NR/rdonlyres/09B3D49A-C353-402F-BB2D-94BCC945C598/0/012006Mar1FinalSection1.pdf • Long-Term and Short-Term Service application forms can be found on our website at http://www.bctc.com/transmission_scheduling/agreements/ • Depending on your type of application you will be required to complete one or more of the following: • Umbrella Agreement • Application Form • Customer Contact Form • Sworn Statement Scheduling 101

  13. Other Required Permits • Depending on your type of application you will also require the following: • NEB Permit if you plan to export energy generated in Canada to the US or Mexico • DUNS Number • Register company on TSIN @ www.tsin.com • Digital Certificates and software for OATI OASIS (approximate cost $175 USD / year) • Digital Certificates and software for E-tag (price negotiable with E-tag vendor) • Hardware and software specifications that meet the requirements of both OASIS and E-tag (computer with secure internet browser) Scheduling 101

  14. Paths Scheduling 101

  15. British Columbia Transmission Grid • The BC transmission grid is a network of multiple transmission providers’ facilities, the majority being owned by BC Hydro • The grid is currently operated as a whole to: • move electricity from generating stations to distribution substations where it is transformed to lower voltages to serve customers • import, export and wheel energy to/from other Control Areas • provide reliability services to the rest of the interconnection • To sell transmission services, BCTC breaks the transmission network into paths which include the two interties with the US and Alberta Scheduling 101

  16. What Transmission Paths Do I Use? Table 1 of Section 5 of BCTC’s Business Practices sets out the Paths and POR/POD Combinations Guide, which is located on our website at http://www.bctc.com/NR/rdonlyres/29E67494-7936-4590-9288-7FCBD40B104F/0/052006Mar1FinalSection5.pdf Scheduling 101

  17. What Transmission Paths Do I Use? • BCTC developed an interactive Scheduling Path Map customers can use to identify which paths and associated PORs/PODs are required to get their energy from the source to the sink • The 5 screens are located on our website at http://www.bctc.com/the_transmission_system/system_overview_maps/scheduling_path_map.htm Scheduling 101

  18. TTC/ATC Scheduling 101

  19. TTC/ATC • WECC Path Rating • WECC Operating Transfer Capability (OTC) • Total Transfer Capability (TTC) • Firm TTC • Transmission Reliability Margin (TRM) • Available Transfer Capability (ATC) Scheduling 101

  20. WECC Path Ratings • Path Rating • The maximum MW that can be demonstrated to flow under realistic and optimistic conditions. • Path Rating for path 1 is: • 1200 MW BC>AB • 1000 MW AB>BC • Path Rating for path 3 is: • 3150 MW BC>US • 2000 MW US>BC Scheduling 101

  21. WECC Approved OTC’s OTC is defined as the maximum amount of electric power that can be transferred reliably over a transmission path • Maximum approved OTC rating for path 1 is: • 1160 MW BC>AB • 1000 MW AB>BC • Maximum approved OTC rating for path 3 is: • 3150 MW BC>US • 2000 MW US>BC Scheduling 101

  22. TTC TTC BCTC’s definition: TTC is defined as the amount of electric power that can be transferred over the interconnected transmission network in a reliable manner while meeting all pre- and post-contingency system conditions. Note: Roughly equivalent to the First Contingency Total Transfer Capability as defined in the May 1995 “Transmission Transfer Capability” NERC document lity (TTC) is roughly equivalent to the First Contingency Total Transfer Capability as defined in the May 1995 “Transmission Transfer Capability” NERC document. Scheduling 101

  23. Firm TTC Generally, BCTC applies n-1 criteria (system normal less one critical element) to determine Firm TTC • Firm TTC is defined as the level that can continue to be served immediately after a single permanent forced outage Scheduling 101

  24. Firm TTC • Section 2.0 of BCTC’s Business Practices sets out TTC/ATC below, which is located on our website at located on our website at http://www.bctc.com/NR/rdonlyres/D9F43D5D-959F-458A-8549-F88D108AE357/0/022006Mar1FinalSection2.pdf • BCHA > AESO: 545 MW • AESO > BCHA: 450 MW • BCHA > BPAT: 1800 MW • LM > BPAT: 1800 MW • BPAT > BCHA: 1800 MW • Other constraints may reduce transfer limits Scheduling 101

  25. Operations and Outages • OTC may be different from “expected” due to: • Operational issues - check bulletins and System Operating Orders, which are located on our website at http://www.bctc.com/transmission_scheduling/bulletins/2006/ and http://www.bctc.com/the_transmission_system/system_operating_orders, respectively • Outages - check Forced and Current Outages webpage and Annual Maintenance Plan, which are located on our website at http://www.bctc.com/the_transmission_system/system_outages/ • Check other Control Area issues Scheduling 101

  26. Interconnected Operation Scheduling 101

  27. TRM TRM • Transmission Reliability Margin (TRM) is used to minimize these type of OTC violations by “setting aside” a reasonable amount of capacity to handle common operating situations • TRM is defined as the amount of TTC necessary to ensure the interconnected transmission network is secure under a possible range of uncertainties in system conditions Scheduling 101

  28. Interconnected Operation with TRM Scheduling 101

  29. Nominal TRM Values • TRM is nominally set at 50 MW in each direction on the intertie with BPAT • TRM is nominally set at 65 MW in each direction on the intertie with AESO Scheduling 101

  30. ATC ATC • Available Transfer Capability (ATC) is a measure of the transmission capability remaining in the physical transmission network for further commercial activity over and above committed uses • ATC = TTC - TRM - Total Commitments Scheduling 101

  31. Transmission Services Scheduling 101

  32. Point-to-Point (PTP) • PTP Transmission Service • PTP can be Firm (long- or short-term) or Non-Firm • Short-Term Firm and Non-Firm • Less than 12 months • Long-Term Firm • 12 months or longer • Rollover Rights • Take-or-Pay based on reservation capacity • POR and POD (Scheduling Points: may or may not be physical points) Scheduling 101

  33. PTP Scheduling 101

  34. NITS • NITS • Long-Term Firm • Standard 10 years term • PORs and PODs • Load/Resource Balance Scheduling 101

  35. Long-Term Transmission Service Scheduling 101

  36. Business Practice 15 • Section 15 sets out BCTC’s Long-Term Business Practice, which is located on our website at http://www.bctc.com/NR/rdonlyres/4EEFF805-EDA2-4975-89C5-FFEAA750BDB7/2046/2006Nov6Section15updated.pdf • BCTC will conduct a study to determine ATC and determine whether or not a System Impact Study (SIS) is required • BCTC will offer one of the following: • Full service • Partial service and a SIS Agreement • Shaped Service and a SIS Agreement • A SIS Agreement Scheduling 101

  37. Business Practice 15 • Business Practice Section 15 • Partial service and a SIS Agreement • Customer may execute either agreement or both • If customer executes only the SIS, partial service will not be offered after SIS • Shaped service and a SIS Agreement • Customer may execute either agreement or both • If customer executes only the SIS, Shaped Service will not be offered after SIS Scheduling 101

  38. Business Practice 15 • SIS to answer the following questions: • What new Network Upgrades are required to provide requested service in full? • Are Re-dispatch options available? Scheduling 101

  39. Business Practice 15 Facilities Study to determine: • Cost of Network Upgrades identified in SIS • Customer’s share of the costs • Timelines Scheduling 101

  40. Procedures and Timelines • Timeline without a SIS • Timeline with a SIS • Complete Timeline Scheduling 101

  41. Procedures and Timelines Timeline without SIS Scheduling 101

  42. Procedures and Timelines Timeline with SIS Scheduling 101

  43. Procedures and Timelines Complete Timeline Scheduling 101

  44. Business Practice 16 Rollover Rights: (OATT Sec. 2.2 & Business Practice Sec. 16) • Submit a new request for Rollover at least 60 days prior to End Date (Rollover Request) • Prior request for a longer term and for the same capacity (Competing Request) • Both requests have the same Start Time • Rollover Request has a Right of First Refusal (ROFR) to match term • The last Rollover Request is required to match first Scheduling 101

  45. Long-term PTP Rollover Rights Scheduling 101

  46. Business Practice 16 Rollover Rights Queue positions: 1 2 3 Scheduling 101

  47. Business Practice 16 Rollover Rights: • Example 1: • Customer A has a 1-year contract for 100 MW (1 Jan 07 End Date) • There are 200 MW ATC • Service Requests: Scheduling 101

  48. Business Practice 16 Rollover Rights: • Example 1: • Based on queue positions: • Customer B: 200 MW for 5 years • Customer A: 0 MW Scheduling 101

  49. Business Practice 16 Rollover Rights: • Example 1: • Based on Rollover Rights • BCTC counteroffers Customer B (200 MW for 5 years) • If Customer B confirms • BCTC asks Customer A to match • If Customer A matches: • Customer A: 100 MW for 5 years • Customer B: 100 MW for 5 years Scheduling 101

  50. Business Practice 16 Rollover Rights: • Example 2: • Customer A has a 1-year contract for 100 MW (1 Jan 07 End Date) • Customer B has a 1-year contract for 100 MW (1 Jan 07 End Date) • There are 200 MW ATC • Service Requests: Scheduling 101