http://elabs7.com/content/1001271/Market%20Notice%20Logo_2011.gifMarket Notice

September 13, 2011

 

 

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ISO News and Information

Legal/ Regulatory

Market Operations

Settlements and Market Clearing

 

 

Resent to correct table description and RTPD definition

 

Resend: Settlement Implications of System Event on 9/8/11 and 9/9/11

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Summary

On September 8, 2011, the California ISO experienced a major system disturbance and temporarily suspended the wholesale real-time energy markets as of 6:00 p.m. (Pacific Time), hour ending 19. The market suspension ended as of 4:00 a.m. (Pacific Time), hour ending 5 on September 9, 2011. The ISO established administrative prices during the period of suspension and will use them to settle the market.

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Main Text

On September 8, the ISO experienced a major system disturbance and temporarily suspended the wholesale real-time energy markets as of 6:00 p.m. (Pacific Time), hour ending 19. The market suspension ended as of 1:00 a.m. (Pacific Time) hour ending 2 on September 9, 2011 for the Pacific Gas and Electric Company (PG&E) and Southern California Edison (SCE) service areas and ended as of 4:00 a.m. (Pacific Time), hour ending 5 on September 9, 2011 for the San Diego Gas and Electric (SDG&E) service area.

 

The ISO established administrative prices during the period of suspension to help ensure reliability. The ISO will use these administrative prices, which replace the Locational Marginal Price (LMP) normally established through the ISO markets, to settle the market. The ISO will be submitting a filing with FERC to request waiver of ISO tariff section 7.7.4(3), which sets the administrative price as the price in the settlement period immediately prior to the settlement period in which the intervention occurred.

 

The table shown below summarizes the pricing established for the time periods from hour ending 17 interval 4 on September 8, 2011 through hour ending 4 on September 9, 2011.

 

 

September 8, 2011

Hour/Interval

Market

Pricing

HE 17 interval 4 - HE 18 interval 12

Real-time dispatch (RTD)

Interval Replacement using HE 16 interval 10.

HE 19 - 22 (all intervals) for all nodes

RTD and Hour-ahead scheduling process (HASP)

Administrative Pricing: Locational Marginal Price (LMP) = $250, energy = $250, congestion = $0 and losses = $0.

HE 23 - 24 (all intervals) for all nodes

RTD and HASP

Administrative Pricing: LMP = $100, energy = $100, congestion = $0 and losses = $0.

HE 17 - 24

Real-Time Pre Dispatch (RTPD)

RTPD A/S prices = Day ahead (DA) A/S prices

HE 19 - 22

HASP Ancillary Service (A/S)

HASP A/S prices = DA A/S prices

 

September 9, 2011

Hour/Interval

Market

Pricing

HE 1 (all intervals) for all nodes

RTD and HASP

Administrative Pricing: LMP = $100, energy = $100, congestion = $0 and losses = $0.

HE 2 - 4 (all intervals) for nodes mapped to SDGE UDC territory only

RTD and HASP

Administrative Pricing: LMP = $100, energy = $100, congestion = $0 and losses = $0.

HE 1

RTPD and

HASP A/S

RTPD and HASP A/S prices = DA A/S prices

 

Expected Energy and Ancillary Service Award Calculations

- Hour ending 19 on September 8, 2011 through hour ending 1 on September 9, 2011 the ISO requested units to follow their day-ahead schedules unless the ISO issued a specific verbal exceptional dispatch to a different operating level.

- Beginning with hour ending 02 on September 9, 2011 dispatches were sent via ADS for units within the PG&E and SCE service areas.

- Units within the SDG&E service area remained on verbal exceptional dispatch through hour ending 4 of September 9, 2011.

- Beginning with hour ending 5 on September 9, 2011, all markets were restored and all dispatches for energy and ancillary services were issued via Automated Dispatch System (ADS).

 

All sections of the ISO tariff remain in effect for settlements purposes. As such, all settlements, including Bid Cost Recovery and Exceptional Dispatch Energy, will be calculated accordingly. Generating units fulfilling resource adequacy contracts that were impacted by the transmission outage should use the outage correction process referenced in section 8.4.1.3 of the Reliability Requirements business practice manual to identify any related unit outages that were caused by the transmission emergency.

 

The ISO tariff is available on the ISO website at http://www.caiso.com/rules/Pages/Regulatory/Default.aspx.

 

The ISO cannot comment on the cause of the system event until analysis is complete, but will field questions about the suspension of the market at the Market Performance and Planning Meeting scheduled tomorrow, September 14, 2011. Details on the meeting are available at http://www.caiso.com/informed/Pages/MeetingsEvents/UserGroupsRecurringMeetings/Default.aspx.

 

Meeting Details

Date: Wednesday, September 14, 2011

Time: 9:00 a.m. - 3:00 p.m. (Pacific Time)

Location: California ISO, 250 Outcropping Way, Folsom, CA 95630

 

Teleconference Information

Dial-in Number: (888) 276-0009

International Dial-in: (612) 338-1040

Conference ID: Not Required

 

Web Conference Information

Web Address: www.webmeeting.att.com

Meeting Number: 8018289903

Access Code: 6292210

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For More Information Contact

Your client representative

The California ISO strives to be a world-class electric transmission organization built around a globally recognized and inspired team providing cost-effective and reliable service, well-balanced energy market mechanisms, and high-quality information for the benefit of our customers.

250 Outcropping Way, Folsom, CA 95630

Glossary of terms and acronyms

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