4 Colo. Code Regs. § 723-3-3606
Current through Register Vol. 47, No. 16, August 25, 2024
Section 4 CCR 723-3-3606 - Electric Energy and Demand Forecasts(a) Forecast requirements. The utility shall prepare the following energy and demand forecasts for each year within the planning period. (I) Annual sales of energy and coincident summer and winter peak demand in total and disaggregated among Commission jurisdictional sales, FERC jurisdictional sales, and sales subject to the jurisdiction of other states.(II) Annual sales of energy and coincident summer and winter peak demand on a system wide basis for each major customer class.(III) Annual energy and capacity sales to other utilities; and capacity sales to other utilities at the time of coincident summer and winter peak demand.(IV) Annual intra-utility energy and capacity use at the time of coincident summer and winter peak demand.(V) Annual system losses and the allocation of such losses to the transmission and distribution components of the system. Coincident summer and winter peak system losses and the allocation of such losses to the transmission and distribution components of the systems.(VI) Typical day load patterns on a system-wide basis for each major customer class. This information shall be provided for peak-day, average-day, and representative off-peak days for each calendar month.(b) Range of forecasts. The utility shall develop and justify a range of forecasts of coincident summer and winter peak demand and energy sales that its system may reasonably be required to serve during the planning period. The range shall include base case, high, and low forecast scenarios of coincident summer and winter peak demand and energy sales, based on alternative assumptions about the determinants of coincident summer and winter peak demand and energy sales during the planning period.(c) Required detail. (I) In preparing forecasts, the utility shall develop forecasts of energy sales and coincident summer and winter peak demand for each major customer class. The utility shall use end-use, econometric or other supportable methodology as the basis for these forecasts. If the utility determines not to use end-use analysis, it shall explain the reason for its determination as well as the rationale for its chosen alternative methodology.(II) The utility shall maintain, as confidential, information reflecting historical and forecasted demand and energy use for individual customers in those cases when an individual customer is responsible for the majority of the demand and energy used by a particular rate class. However, when necessary in the resource plan proceedings, such information may be disclosed to parties who intervene in accordance with the terms of non-disclosure agreements approved by the Commission and executed by the parties seeking disclosure.(d) Historical data. The utility shall compare the annual forecast of coincident summer and winter peak demand and energy sales made by the utility to the actual coincident peak demand and energy sales experienced by the utility for the five years preceding the year in which the plan under consideration is filed. In addition, the utility shall compare the annual forecasts in its most recently filed resource plan to the annual forecasts in the current resource plan.(e) Description and justification. The utility shall fully explain, justify, and document the data, assumptions, methodologies, models, determinants, and any other inputs upon which it relied to develop its coincident peak demand and energy sales forecasts pursuant to this rule, as well as the forecasts themselves.(f) Format and graphical presentation of data. The utility shall include graphical presentation of the data to make the data more understandable to the public, and shall make the data available to requesting parties in such electronic formats as the Commission shall reasonably require.38 CR 17, September 10, 2015, effective 9/30/201539 CR 06, March 25, 2016, effective 4/14/201639 CR 08, April 25, 2016, effective 5/15/201640 CR 22, November 25, 2017, effective 12/15/201742 CR 03, February 10, 2019, effective 3/2/201942 CR 07, April 10, 2019, effective 4/30/201942 CR 09, May 10, 2019, effective 5/30/201943 CR 08, April 25, 2020, effective 5/15/202043 CR 12, June 25, 2020, effective 7/15/202043 CR 20, October 25, 2020, effective 11/14/202044 CR 13, July 10, 2021, effective 7/30/202144 CR 24, December 25, 2021, effective 1/14/202245 CR 18, September 25, 2022, effective 10/15/202246 CR 02, January 25, 2023, effective 2/14/2023