4 Colo. Code Regs. § 723-3-3531
Current through Register Vol. 47, No. 11, June 10, 2024
Section 4 CCR 723-3-3531 - Assessment of Existing Distribution System(a) System overview and substation historical data.(I) To identify and assess needs on the distribution system, each utility shall provide a map of existing and planned substations within its service territory, as well as tabular information about the current design capacity, and performance of each substation and substation transformer. The assessment should also include the status of advanced metering infrastructure deployment which may be made by reference to other reports or filings. At a minimum, this should include the following information for each substation and substation transformer on the utility's distribution grid: (A) maximum rated capacity of each substation transformer;(B) peak hourly demand on each substation transformer for the past three years;(C) capacity margin for each substation transformer;(D) advanced functionality capabilities of each substation transformer;(E) number of feeders served by each substation and substation transformer;(F) maximum rated capacity of each feeder;(G) peak hourly demand on each feeder for the past three years; (H) capacity margin for each feeder;(I) percentage of grid availability;(J) minimum daytime load;(K) aggregate miles of underground and overhead wires, categorized by voltage class;(L) monitoring capabilities and data collection on the distribution system, such as the substations and feeders for which the utility has real-time supervisory control and data acquisition (SCADA) capability;(M) amount of distributed generation installed on the system (number of systems and nameplate capacity in kilowatts (kW) by generator types, organized by substation or feeder);(N) description of NWA on the system, organized by substation or feeder; including annual cost savings and greenhouse gas emissions reductions;(O) amount and locations of distributed storage installed on the system (number of systems and ratings, measured in kilowatts and kilowatt-hours (kW and kWh));(P) estimated number of EVs and Level 2 and DCFC EV charging stations organized by substation or feeder;(Q) estimated demand flexibility capacity on the system and historic utilization of those flexibility capabilities;(R) voltage and power quality data for the past three years; and(S) location of highly seasonal circuits as defined by subparagraph 3667(a)(IV).(II) Hosting capacity analysis. (A) As part of its DSP, each utility shall develop a hosting capacity analysis of the distribution system.(B) The analysis shall determine the hosting capacity on a particular feeder, feeder section or substation at a given time under existing and forecasted grid conditions and operations without adversely impacting safety, power quality, reliability, or other operational criteria.(C) The hosting capacity analysis shall be performed using a load flow analysis and forecasted distribution facilities and their capacity, configuration, loading, and voltage data gathered at the substation, feeder, and primary node levels where available.(D) The utility shall perform scenario analysis to evaluate hosting capacity need under normal, planned contingency, and unplanned contingency conditions, for both the State Policy and High Growth scenario.(E) The utility shall provide a detailed description of the methods and outcomes it used to perform the hosting capacity analysis.(F) The hosting capacity analysis shall reflect that which appears in the web portal as described in rule 3541. The utility shall also provide a detailed narrative describing the utility's progress towards advancements to the accuracy and value of the hosting capacity analysis and providing real-time hosting capacity data. This should include a description of how its hosting capacity analysis currently advances customer-sited DER (in particular distributed renewable electric generation and energy storage systems), how the utility anticipates the hosting capacity analysis will aid in identifying interconnection points on the distribution system and necessary distribution upgrades to support the continued development of distributed generation resources, and any other method in which the utility anticipates customer benefit stemming from the hosting capacity analysis.(G) For their first DSP filing, utilities with 500,000 or fewer customers shall provide an Excel spreadsheet (or equivalent format) by feeder of either daily daytime minimum load or, if daytime minimum load is not available, daily peak load with the time granularity specified. If daytime minimum load or daily peak load data are unavailable, the utility shall explain why the data are unavailable.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