6. A plotting and a description of the base case for load flow studies of the bulk power network of the region (or principal subdivisions) as it exists, substantially, at the time of reporting and as projected four to six years in the future; and a tabulation and brief statements on the results of a representative number of contingency cases studied; and similarly, information on stability analyses of the network, and including the criteria adopted by the regional council relating to network stability. 7. A description of the principal communication and control systems operating or planned within the region and listing of functions performed by such facilities. (To be reported initially and updated in subsequent reports when significant changes occur.) 8. For each transmission segment designed to operate at 230 kv (nominal) or higher for which construction has begun or is scheduled to begin within two years from the date of the report, information on the status of consultations with affected local communities and groups, and status of applications to State or regional authorities, as appropriate. Information on the following coordinated regional practices: (To be reported initially and updated in subsequent reports when significant changes occur.) 9. a. b. Load shedding programs, including estimated steps of load reduction at various steps in declining frequency. Emergency power and shutdown facilities to prevent C. Power facilities available for unit startup in the d. e. f. 8. Availability of continuous power independent of system sources for communication and control facilities. Provisions for sustaining the operation of generating Programs for scheduling maintenance outages of generation and transmission facilities. Programs for the selection, setting and maintenance of relays that affect the overall reliability of the interconnected network. APPENDIX D Load Supply Tabulations for 1970 Summer Peak Period FEDERAL POWER COMMISSION REGIONAL OFFICE 610 South Canal Street, Room 1051 Chicago, Illinois 60607 MEMORANDUM TO ALL UTILITIES IN THE WEST CENTRAL REGION May 1970 Attached for your information is a summary analysis of the reported loads and available supply of electric utilities in the West Central Region during the coming summer peak season, June through September 1970. The Region consists of the Federal Power Commission designated Power Supply Areas 13, 14, 15, 16, 17, 26, 27, 28 and 40. This includes all of the states of Illinois, Iowa, Minnesota, North Dakota, South Dakota, and Wisconsin; and parts of Michigan, Missouri, Montana, Nebraska and Wyoming. The attached map shows the geographical location of the area. The enclosed tabulation is based primarily on data reported by the principal electric systems or pools in the Region to the Commission on FFC Form No. 12-E, Monthly Power Statement, for January 1970. The Iowa pool, consisting of six utilities, submits a consolidated Form 12-E report. The 12-E reporting systems represent the major portion of the total utility capacity and energy requirements in the Region. The tabulation compares estimated 1970 summer peaks with generating capacity expected to be in service at the end of May 1970, increased or decreased by firm purchases or obligations expected to be in effect at the time of the summer peak. Since the cut-off date for capacity additions is the end of May, a supplemental tabulation is included showing scheduled capacity changes during June, July and August. If scheduled additions become commercially available for service by the time of the summer peak, the figures on capacity available for reserves should be adjusted accordingly. The summaries reflect only those intersystem transfers that are reported to be covered by firm contracts. No endeavor has been made to account for emergency measures that might be resorted to for the purpose of matching power requirements and supply, such as dropping interruptible loads and reducing voltage. Likewise, no reduction in dependable capacity has been considered due to scheduled maintenance of units or other factors. To ensure the probability that system load demands can be met, sufficient capacity must be provided not only to meet the expected peaks of the load but also to provide adequate reserve capacity to compensate for forced outages, required maintenance, and other reasonable contingencies. Many systems plan reserves in an amount which may range from about 10 to 20 percent of the expected system peak load demands. The West Central Region as a whole has an indicated reserve margin of 4,371 megawatts or 12.7 percent of the estimated summer peak. The indicated reserves for a number of the reporting systems appear to be marginal. Furthermore, some of the margins are dependent upon imports from external systems during peak load periods. Based on actual system capacity, it appears that some systems will not have sufficient reserves of their own during the coming summer. The Union Electric Company, in PSA 15, showing less than one percent capacity available for reserves, has 555 mw of new capacity scheduled to be in service by the time of its system's peak. This addition (Labadie Unit #1-Fossil Steam), which will increase the capacity available for reserves to 14.1 percent, is expected to contribute to system load beginning in May. Similarly, the Northern States Power Company has a 460 mw capacity addition (Monticello #1 Unit-Nuclear) scheduled to be in service by the time of its system peak in July. Capacity available for reserves will then increase to 12.1 percent. The possible dependence of these systems on power imports from other utilities makes it imperative that operations be coordinated adequately to ensure the availability of supplemental power when needed. The coordination arrangements will need to cover both the availability of standby generation on the interconnected systems and operational planning to maintain network loading which will permit the required power transfers to meet peak loads and maintain adequate transmission reserves. While only firm purchases and sales have been included, additional capacity can be made available through interconnected systems within the Region on a non-firm, short-term basis if an emergency should develop. When reviewing the probability that system load can be met, consideration must be given to other potential factors. Among these are, labor developments such as the recent General Electric Company strike affecting inservice dates of critical generating and transmission facilities, fuel supplies as affected by source and transportation problems, weather conditions contributing to outages or reduction in system output, and simultaneous outages of large increments of system capacity. A copy of this memorandum and the tabulation is being furnished to each State Commission in the West Central Region and to each utility in the Region which reports or participates in reporting on the FPC Monthly Form 12-E. Attachments: NPS Regions Map ་ བདཊཱ་ Далай Lenard B. Young Load Supply Tabulation for 1970 Summer Peak Period 1/ 2/ Federal Pover Commission April 1970 Sheet 1 of 5 PSA Utility 1/30/70 By 5/31/70 Firm Purchases Firm Sales Capacity Peak & Month for Reserves Peak Load 1/ June through September 1970. 2/ Data from FPC Form No. 12-E for January 1970. 3/ Summer rating. Totals are noncoincident summer peak demands. Refer to supplemental tabulation for any changes in capacity scheduled for June, July or August. Wisconsin Electric Power Company maintains reserve capacity for Wisconsin Michigan Power Company. Load Supply Tabulation for 1970 Summer Peak Period 1/2/ (Megawatts) Federal Power Commission Chicago Regional Office Sheet 2 of 5 5/ Refer to supplemental tabulation for any changes in capacity scheduled for June, July or August. 6/ Capacity addition (555 m) shown in the supplemental tabulation for July dependable capacity is expected to contribute to load in varying amounts beginning in May. 1/ If capacity (460) shown in supplemental tabulation, scheduled to be in service July 1, 1970, is delayed, purchases will be made to cover deficit and provide reserves of 12 percent minimum. |