January 14, 2016

PacifiCorp-CAISO-NVEEIM Initiative Overview

Agenda• Introduction• PacifiCorp background• Real-time operations of EIM• Challenges• Current status

PacifiCorp customers

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Investor owned utility – subsidiary ofBerkshire Hathaway Energy6,447 staff in U.S.1.8million customers in 6 states

Utah (42%)Oregon (25%)Wyoming (17%)Washington (8%)Idaho (6%)California (2%)

PacifiCorp Peak Load:12,558 MWPACW: 4354 MW80+ Ties with other Balancing AreasPACE: 8989 MW50+ Ties with other Balancing Areas

EIM FootprintPacifiCorp• 1.7 million customers • 9,500 MW peak demand• 10,600 MW generating capacityNV Energy• 1.2 million customers• 8,148 MW peak demand• 5,815 MW generating capacityCAISO• 11.4 million customers• 50,280 MW peak demand• 58,246 MW generating capacityPSE and AZPS• Coming soon….

EIM Concept• What is an EIM

– It is not an ISO– It is not balancing our BAA

• EIM in real-time– Generation redispatch– Forward looking transmission management

• BAA’s responsibilities– Not changing– New tools and processes

Variable Energy Operation

EIM Real-Time Operations• Timing criticality of a 5 minute system• Base Schedules• Hourly vs. 15 minute vs. 5 minute markets• Dispatches• Transmission congestion• Outages

Operational Concept Overview• Expansion of CAISO’s current 5 minute market

– Security Constrained Economic Dispatch• Transmission constraint management• Network model visibility and accuracy • Terminology:

– Market Operator, EIM Entity, Participating Resources, Manual Dispatch, Instructed/Uninstructed Imbalance charges, Scheduling Coordinator…..

• Detailed outage reporting and situational awareness

Base Schedules• Entity must come to the market balanced• Base Schedule (G + I = L) (feasibility check)

– Forecast of load – Forecast of generation– Forecast of interchange

• Submitted by all customers to EIM Entity• Data aggregated and validated by PacifiCorp Grid• Entity retains all BAA responsibilities

Base Schedule data flow (via SCs)

Balance and Feasibility Tests• Base Schedule Balancing Test• Bid Range Capacity Test• Flex Ramp Required Sufficiency Test• Transmission Feasibility Test

Hourly vs. 15 minute vs. 5 minute• Hourly market (HASP)

– Unit start up, shut down, and transitions• 15 minute market (RTPD)

– Market awards, e-tags– Runs approx. 40 minutes ahead

• 5 minute market (RTD)– Dispatches based on 15 min awards– Runs approx. 7.5 minutes before ramp

Dispatch• Dispatch sent to PacifiCorp’s Ranger (EMS), to RTU,

and to the plant

Transmission Congestion• Forward looking congestion management• 15 minute market awards published for 8+

intervals• Correcting limits in state estimator• Collaboration between Energy Grid Operator

(EIM desk) and TO desks

Outage Reporting Requirements• Outage reporting is critical to SE and dispatches• Planned outages must be submitted at least 7 days in

advance– For EIM, at least seven days

• Forced outages must be reported within 30 minutes– Less imbalance the sooner it is reported

• PAC using COMPASS to interface to CAISO’s OMS • Market run criticality

PAC and CAISO responsibilities• PAC retains all reliability function responsibility• PAC will balance their ACE, manage reserves (no

impact to NWPP RSG) and manage their voltage • Under EIM, CAISO operates the market and publishes

market results for both PAC and CAISO (the EIM footprint)

• Under EIM, PAC will operate transmission, monitor generation, process outages, and balance ACE for PACW and PACE

Challenges (go-live)Go-live• Typical IT software refining• Accuracy of generation unit

outages and derates for informing market

• Disciplined generation and interchange resource plan that aligns with market

• Network model accuracy• Change management

Updates• System accuracy increasing

• Reaching granular aspects of base scheduling

• Network model aligned with CAISO and updated monthly

• Evolution of change management– (ongoing but evolving)

Challenges (current)• Change management evolution

– Understanding market actions• Outage management tools upgrades

– New webOMS system• Seasonal strategies

– Fuel restrictions• NVE incorporation

– New dynamic transfers– Networks the BAAs, rather than radial

Current Status• Continue updates of network model• Available Balancing Capacity testing

– January• Continued focus on transmission constraints• Solar integration

Questions

• John Schaffroth(503) 251-5154john.schaffroth@pacificorp.com