TEPPC Needs from VGS

1. TEPPC Needs from VGS VGS MWG Meeting June 9, 2011 Jamie Austin, PacifiCorp TEPPC Liaison to VGS

2. TEPPC Needs from VGSSlides 2 & 3: A summary circulated at the TEPPC meeting • Of particular use to TEPPC between now and mid 2012? (Sooner?) • Completion of Planning Guide – guidelines for including VG in planning • Update of VGS Whitepaper, January 2011 • Operating practices • Scheduling Practices • Business Practices (incl. market products) • Commercial terms of PPAs • Imbalance market (Efficient Dispatch Tool) • Dynamic Transfer potential • Transmission ratemaking • Inter-BA coordination

3. TEPPC Needs from VGS (Continued)Slides 2 & 3: A summary circulated at the TEPPC meeting • Premise: VGS and/or OC, MIC, and PCC are addressing many of the operational, reliability, vulnerability, and market interface issues around integration of variable generation. • A matrix of activities across groups would be useful. • Status report and estimated completion dates for PWG activities

4. High Level - TEPPC Modeling ConcernsDiscussed at the TEPPC Meeting, held May 25, 2011 • Historically, the transmission system was tuned to achieve maximum transfer limits, and around traditional resource mix. • Times have changed: variable, intermittent resources are increasing and prompting the need to consider: • Within the hour frequency and magnitude of increasing ramps • Remote high quality renewable require delivery of balancing and other Action Schemes over long distance transmission • Amount of “must run” renewable – displacing fast acting thermal generation • Generation mix changing - Need for more balancing and regulation – where, who and how

5. Regional Studies • The CAISO, BPA and Powertech Lab Dynamic Transfer Capability (DTC) studies all showed voltage change at critical busses to be a key component in determining increased DTC limits; • Continued reliance on manual actions for RAS arming and voltage control may hinder the expanded use of Dynamic Transfers; • Report can be found at: http://www.columbiagrid.org/DTCTF-overview.cfm

6. ColumbiaGrid Dynamic Transfer Capability Task Force Overview - • Process:  Under the auspices of the Wind Integration Study Team, convene a Taskforce of transmission experts to: • Identify the limitations on DTC and quantify the threats to system reliability and costs of increased dynamic transfers; • Understand differences in methodology for calculating DTC limits; • Characterizing the types of use of DTC for different generators (e.g. Wind vs Coal), Loads ( e.g. internal vs remote load) and Schedules (Regulation, Spinning Reserve, Contingency Reserve, 30 minute static & 60 minute static); • Identify possible short-term, medium-term and long-term options for reliably increasing DTC in the Pacific Northwest.

7. The TEPPC Needs • TEPPC studies have been implemented without increased reserves, beyond what’s been assigned for conventional generation configuration; • What options does TEPPC have meantime, until VGS quantifies “supplemental” reserves need? • Discussed other options to consider: analysis comes from injection models • Renewable providing own balancing • Firming gas plants for balancing • The FERC 15 min markets – what committees are going to get into this; need to look at how the west moves? • Consistent with the VGS effort, it would help to have a log into what studies are available – log to a library • The need to look at the system from the regional perspective • VGS intra hour studies – timing schedule? • Who will bring it all together? • Concern that VGS has the expertise to produce what’s needed;