2015 Local Capacity Requirements Qualifying Capacity 2015 LCR Need Based on Category B 2015 LCR Need Based on Category C with Operating Procedure Local Area Name QF/ Muni (MW) Market (MW) Total (MW) Existing Capacity Needed Deficiency Total (MW) Existing Capacity Needed** Deficiency Total (MW) Humboldt 36 171 207 116 0 116 166 0 166 North Coast / North Bay 130 771 901 550 0 550 550 0 550 Sierra 1299 771 2070 1392 29* 1421 1803 397* 2200 Stockton 197 392 589 357 0 357 396 311* 707 Greater Bay 1262 6243 7505 3492 0 3492 4231 136* 4367 Greater Fresno 316 2532 2848 2393 0 2393 2393 46* 2439 Kern 408 87 495 108 26* 134 411 26* 437 LA Basin 2208 8985 11193 8620 0 8620 9097 0 9097 Big Creek/ Ventura 1160 4203 5363 2095 0 2095 2270 0 2270 San Diego Imperial Valley 219 4328 4547 3910 0 3910 3910 202* 4112 Total 7235 28483 35718 23033 55 23088 25227 1118 26345
NOTE: All numbers are in MegaWatts CAISO System Flexible Requirement CPUC Category 1 Category 2 Category 3 Flexible Requirement (minimum) (100% less Cat. 1 & 3) (maximum) January 9,459 8,972 6,639 1,884 449 February 10,465 10,099* 7,473 2,121 505 March 9,543 9,025 6,679 1,895 451 April 8,468 8,005* 5,924 1,681 400 May 7,520 7,134* 4,851 1,926 357 June 9,078 8,707 5,921 2,351 435 July 8,083 7,694 5,232 2,077 385 August 7,861 7,464* 5,076 2,015 373 September 8,523 8,126 5,526 2,194 406 October 10,381 9,818* 7,265 2,062 491 November 10,848 10,460 7,740 2,197 523 December 11,212 11,035 8,166 2,317 552 *These values are calculated by adding the numbers in the addendum to the Flexible Capacity Assessment filed May 5, 2014 (Revised Table 8). The marked numbers differ from the Flexible Capacity Need table (Figure 7) by 1 megawatt in the Flexible Capacity Assessment filed May 1, 2014. For allocation among LSEs we will use numbers in the above table. In addition, the CAISO proposes to divide the flexible capacity needs into three categories. These categories are defined based on the CAISO’s assessment of the different types of flexible capacity needed to address the CAISO’s needs. Specifically, in the flexible resource adequacy criteria and must offer obligation (FRAC-MOO) stakeholder initiative, the CAISO proposed the following flexible capacity categories: Category 1 (Base Flexibility): Operational needs determined by the magnitude of the largest 3-hour secondary ramp. Category 2 (Peak Flexibility): Operational needs determined by the difference between 95% of the maximum 3-hour net-load ramp and the largest 3-hour secondary net-load ramp.
Discussion While we appreciate the need to comply with the requirements of SB 2 (1X) as quickly as possible, we agree with parties that many issues remain to be resolved prior to Commission adoption of an ELCC model and ELCC-based QC values for wind and solar resources. Most importantly, the current schedule no longer allows sufficient time for vetting and iteration. Therefore, we do not adopt an ELCC-based QC methodology for wind or solar resources at this time. Because we are not adopting an ELCC-based QC methodology at this time, the QC values for wind and solar resources shall be determined for 2015 according to the exceedance methodology adopted in D.09-06-028 (see Appendix B of D.09-06-028). However, in light of the importance of complying with SB 2 (1X), we direct Energy Division to further develop its ELCC proposal and address the issues identified above such that an ELCC-based QC methodology can be considered by the end of 2014. We understand that this methodology may be only a first iteration in addressing the complex technical issues associated with ELCC calculations, and that the methodology may require additional refinement over time. Comments on Proposed Decision The proposed decision of the ALJ in this matter was mailed to the parties in accordance with Section 311 of the Public Utilities Code and comments were allowed under Rule 14.3 of the Commission’s Rules of Practice and Procedure. Comments were filed on June 16, 2014, and reply comments were filed on June 23, 2014. The proposed decision was modified to account for comments. Assignment of Proceeding Michel P. Florio is the assigned Commissioner and David M. Gamson is the assigned Administrative Law Judge in this proceeding.
depend on the Flexible RA category for which the resource wishes to qualify, as described in the recently-approved CAISO FRAC-MOO proposal. The DRP must receive advance notification as specified in the applicable tariff. For example, a resource with a tariff that requires four hours of advance notice must still receive at least four hours’ notice of the test dispatch in order for the test to be accepted by the Commission. If there is an applicable CAISO test for a given DR resource qualifying as Flexible, System, or Local RA, then that test data is required to be submitted by the LSE showing the resource in its RA compliance filing, and is sufficient to meet Commission testing requirements. For example, the testing proposed in the CAISO FRAC-MOO initiative would apply to DR resources wishing to qualify as Flexible RA, if adopted by FERC. If there is not an applicable CAISO test, then the LSE must test performance in accordance with the following requirements, and submit the results to the Commission along with its RA compliance filings: For Flexible RA resources, testing must comply with the requirements discussed above, such as two-hour testing. It must occur within a three-month period chosen by the demand response provider, with the date and time randomly selected by the LSE (within the date and time constraints of the DR resource, as described in its tariff). System and Local RA resources must submit to similar testing; however, this testing may be conducted at a time of the operator’s own choosing, rather than at a time selected by the CAISO. The timing shall nevertheless be constrained to the standard availability assessment hours that apply to System and Local RA resources. Successful testing to qualify as Flexible RA will be deemed sufficient for qualification as System and Local RA, provided that the program design complies with those product types. Namely, the program must be available during at least four of the standard availability assessment hours each day to