Oklahoma Administrative Code › Title 165 - Corporation Commission › Chapter 35 - Electric Utility Rules › Subchapter 37 - Integrated Resource Planning › Section 165:35-37-4 - Integrated Resource Plan Reviews

Current through Vol. 41, No. 20, July 1, 2024
(a) Each utility shall submit to the
				Commission a proposed integrated resource plan. The utility's first integrated
				resource plan was due on October 1, 2006, and subsequent plans shall be due
				every three (3) years thereafter, unless the utility requests an extension from
				the PUD Director or the utility requests a waiver from the Commission. The
				extension granted by the PUD Director shall not exceed six (6) months.
				Subsequent plans shall be developed and submitted as provided by the procedure
				set forth in OAC
				165:35-37-5. The proposed
				resource plan shall include, among other things, a fuel procurement plan,
				purchased-power procurement plans, a risk management plan, an environmental
				compliance plan, and other elements as described further in this Subchapter.
				This plan will be made available upon request by any person or entity to the
				soliciting utility, except any portions subject to a Commission protective
				order.
(b) Each utility shall have
				an ongoing obligation to monitor markets and inputs and to notify the
				Commission when material changes in planning assumptions occur. As the
				integrated resource plan changes from year to year, the utility shall submit
				updates to the Commission. The Commission may require the utility to submit an
				interim, updated integrated resource plan to reflect material change(s) in
				planning assumptions.
(c) The
				integrated resource plan shall include, at a minimum, a tabular summary of each
				of the following Sections:
(1) Schedule A: An
				electric demand and energy forecast;
(2) Schedule B: A forecast of capacity and
				energy contributions from existing and committed supply- and demand-side
				resources;
(3) Schedule C: A
				description of transmission capabilities and needs covering the forecast
				period;
(4) Schedule D: An
				assessment of need for additional resources;
(5) Schedule E: A description of the supply,
				demand-side and transmission options available to the utility to address the
				identified needs;
(6) Schedule F: A
				fuel procurement plan, purchased-power procurement plan, and risk management
				plan;
(7) Schedule G: An action
				plan identifying the near-term (i.e., across the first five [5] years) actions
				that the utility proposes to take to implement its proposed resource plan;
(8) Schedule H: Any proposed
				RFP(s), supporting documentation, and bid evaluation procedures by which the
				utility intends to solicit and evaluate new resources; and
(9) Schedule I: A technical appendix for the
				data, assumptions and descriptions of models needed to understand the
				derivation of the resource plan.
(10) Schedule J: A description and analysis
				of the adequacy of its existing transmission system to determine its capability
				to serve load over the next ten (10) years, including any planned proposed
				changes to existing transmission facilities.
(11) Schedule K: An assessment of the need
				for additional resources to meet reliability, cost and price, environmental or
				other criteria established by the Commission, the State of Oklahoma, the
				Southwest Power Pool, North American Electric Reliability Council, or the
				Federal Energy Regulatory Commission. This assessment should address both base
				line forecast condition and important uncertainties, including but not limited
				to load growth, fuel prices, and availability of planned supplies.
(12) Schedule L: An analysis of the utility's
				proposed resource plan and any alternative scenarios necessary to demonstrate
				how the preferred plan best meets the planning criteria. Technical appendices
				should be included to document the planning analysis and assumptions used in
				preparing this analysis.
(13)
				Schedule M: A description and analysis of the Utility's consideration of
				physical and financial hedging to determine the Utility's ability to mitigate
				price volatility for the term covered by the IRP.