Operator Corp. 160 FERC ¶ 61,058 (2017) at P 26 (“September 7 Order”) (noting that the Powerex participation agreements would be separately filed by the CAISO pursuant to section 205 of the Federal Power Act).
Operator Corp. 143 FERC ¶ 61,298 (June 28, 2013); Cal. Indep. Sys. Operator Corp., 147 FERC ¶ 61,200 (June 13, 2014), Cal. Indep. Sys. Operator Corp., 151 FERC ¶ 61,158 (May 19, 2015), Cal. Indep. Sys. Operator Corp., 152 FERC ¶ 61,090 (July 31, 2015), Cal. Indep. Sys. Operator Corp., 154 FERC ¶ 61,020 (January 19, 2016); Cal. Indep. Sys.
Operator Corp. 137 FERC ¶ 61,194 (2012) 10 A copy of the board memorandum and resolution accepting Valley Electric’s application is included as Attachment C to this filing. The appendix A for Valley Electric identifies two contracts that provide Valley Electric with all rights necessary to perform its obligations as a participating transmission owner. The first is between Valley Electric and Western – DSR. This agreement entitles Valley Electric to deliver and receive power on the bus at the Xxxx substation. The ISO controlled grid is also connected to the Xxxx substation. As explained more fully in the Transition Agreement, the ISO will assume operational control of Valley Electric’s transmission system across the Xxxx substation bus utilizing this entitlement prior to the completion of a new point of interconnection between Valley Electric and the ISO controlled grid at the Eldorado substation. The second entitlement identified in Valley Electric’s appendix A is referred to as the Use and Entitlement Agreement, which is an agreement between Valley Electric and Valley Electric Transmission Association, LLC (“VETA”).11 VETA is a wholly owned subsidiary of Valley Electric that holds all of Valley Electric’s transmission assets. The Use and Entitlement Agreement provides that Valley Electric will have the exclusive right to use, operate and maintain all existing and future transmission assets held by VETA. It also requires Valley Electric and VETA to comply with the withdrawal and sale or disposition provisions included in sections 3.3 and 4.4 of the TCA, respectively, prior to any termination of the Use and Entitlement Agreement. Valley Electric, pursuant to its entitlements with VETA and Western DSR, has all of the rights and obligations necessary to be a participating transmission owner pursuant to the TCA.12
Operator Corp. 139 FERC ¶ 61,198 at P 18 (2012); Cal. Indep. Sys.
Operator Corp. Commission Letter Order, Docket No. ER13-71-000 (Nov. 6, 2012).
Operator Corp. 151 FERC ¶ 61,158 (2015); Cal. Indep. Sys. Operator Corp., 152 FERC ¶ 61,090 (2015); Cal. Indep. Sys. Operator Corp., 154 FERC ¶ 61,020 (2016)). 12 Id. at 4-5. 13 Id. at 5. fee is based. Moreover, as noted by CAISO, the Implementation Agreement is consistent with similar agreements between CAISO and other balancing authorities that have been accepted by the Commission.14 Accordingly, we accept the Implementation Agreement for filing, effective July 1, 2016, as requested. By direction of the Commission. Xxxxxxxxx X. Xxxxx, Xx., Deputy Secretary.
Operator Corp. 143 FERC ¶ 61,298 (2013); Cal. Indep. Sys. Operator Corp., 147 FERC ¶ 61,200 (2014), Cal. Indep. Sys. Operator Corp., 151 FERC ¶ 61,158 (2015), Cal. Indep. Sys. Operator Corp., 152 FERC ¶ 61,090 (2015), Cal. Indep. Sys. Operator Corp., 154 FERC ¶ 61,020 (2016); Cal. Indep. Sys. Operator Corp., 155 FERC ¶ 61,311 (2016); Commission Letter Order, Docket No. ER17-868-000 (Mar. 14, 2017); Commission Letter Order, Docket No. ER17-1300-000 (May 18, 2017); Commission Letter Order, Docket No. ER17-2120-000 (Sept. 7, 2017); Cal. Indep. Sys.
Operator Corp. 160 FERC ¶ 61,058 (2017); Commission Letter Order, Docket No. ER17-2559-000 (Nov. 16, 2017); Commission Letter Order, Docket No. ER19-1080-000 (Apr. 5, 2019); Commission Letter Order, Docket No. ER19-1080-000 (Apr. 5, 2019); Cal. Indep. Sys. Operator Corp., 170 FERC ¶ 61,168 (2020); Commission Letter Order, Docket No. ER20-596-000 (March 13, 2020); Commission Letter Order Docket No. ER20-2688-000 (October 7, 2020); and Commission Letter Order, Docket No. ER21-1003- 000 (March 26, 2021). Xxxxxxxxx Xxxxxxxx X. Bose September 28, 2021 agreement with the Bonneville Power Administration and reflects provisions appropriate for a federal entity.9 Under the Implementation Agreement, the CAISO and WAPA must complete a variety of project tasks necessary for implementation by April 5, 2023. The parties chose this date to provide sufficient time for completion of all expected activities based on the size, complexity, and compatibility of WAPA, including filing a certification of readiness with the Commission. The specific tasks may be modified by mutual agreement of the parties.10 The Implementation Agreement also includes several principles recognized by the parties regarding the implementation of WAPA’s potential participation in the EIM.11 WAPA’s EIM implementation and participation will be consistent with its statutory, regulatory, and contractual requirements, while remaining voluntarily consistent with the CAISO and WAPA tariffs. WAPA will continue to be responsible for the reliable operation of its generation and transmission system, and will retain the exclusive right to determine what is required to maintain reliability within its balancing authority area and on its transmission system. To that end, the parties will work to ensure that WAPA’s EIM participation will not interfere with WAPA’s existing obligations and will explore whether the developing EIM sub-entity proposal would be appropriate for qualified entities within WAPA’s balancing authority area. At all times, EIM transfers to California will be implemented consistent with the cap and trade program administered by the California Air Resources Board. The Implementation Agreement specifies that WAPA will pay a fixed implementation fee of $285,000, subject to completion of six specific milestones for recovery of the portion of the costs attributable to the CAISO’s effort to configure its real-time market systems and incorporate WAPA into the EIM.12 The methodology that the CAISO used to determine the i...
Operator Corp. 164 FERC ¶ 61,148, at PP 8-9 (2018). The Xxxxxxxxx Xxxxxxxx X. Bose March 5, 2021 become effective on dates as necessary to support schedules associated with the addition of transmission facilities and other transactions involving entitlements. Consequently, the CAISO is willing to forego its usual preference for implementation of transmission access charge revisions for new participating transmission owners on July 1 or January 1 as prescribed by CAISO tariff section 4.3.1.1, since the effective date requested for Morongo is other than January
Operator Corp. 174 FERC ¶ 61,059 (2021) (accepting the rules applicable to pseudo-ties of shared resources to the CAISO balancing authority area); and Cal. Indep. Sys. Operator Corp, 171 FERC ¶ 61,262 (2020) (accepting a split resource participation agreement between the CAISO and the Calpine Xxxxxx Energy Center). 4 CAISO Tariff, Section 29 (establishing the rules applicable to participation in the EIM); see also, Cal. Indep. Sys. Operator Corp., 149 FERC ¶ 61,005 (2014). 5 See CAISO Tariff, Appendix A, Generating Unit (defined as including resources pseudo-tied to the CAISO balancing authority area and, for purposes of the real-time market participation only, resources located in an EIM entity balancing authority area). another balancing authority area is not physically represented in the market model— only the individual resource shares are logically modeled in the market. This modeling limitation is a less optimal solution because the individual resource shares are not linked to a physical resource in the market model. Further, the sharing of pseudo-tied resource shares places a burden on the resource share owners to coordinate operation of the shared resource and allocate the output to the individual shares in separate balancing authority areas.7 The CAISO has yet to fully develop software capable of physically modeling a resource and concurrently allocating the resource’s attributes to logical resource shares participating in the market.8 This means that the modeling of shared pseudo-tie resources as separate market resources is limited to simple generators with a non- negative minimum load, start-up and minimum-load costs, and a single operating range.9 The Agreement would support market resource participation by individual shares derived from one resource through enhanced modeling.10 Thus, the JOU Pilot would produce a more optimal market solution and alleviate the burden currently placed represents a share of a multi-stage generating Resource from registering that share in accordance with Section 27.8, and excusing the CAISO from modeling specific resource characteristic that it otherwise would model if the resource were registered as a multi-stage generating resource, or that represents a forbidden operating region). Similarly, the JOU Pilot resources will not be registered in the market as multi-stage generating units to allow for greater resource sharing flexibility. This modeling capability and the balance between flexibility to support resource sharing arra...
