1. Pacific Power Smart Grid Report 2016 OPUC Public Meeting December 6, 2016

2. Presenters Curtis Mansfield Jake Barker Pacific Power
Vice President, T&D Operations
Jake Barker
PacifiCorp
Manager, Engineering Technical Services & Smart Grid

3. Pacific Power and Oregon Public Utility Commission Smart Grid Goals Alignment
Docket UM Order No
Enhance the reliability, safety, security, quality, and efficiency of the transmission and distribution systems
Enhance customer service and lower costs
Enhance the ability to save energy and reduce peak demand
Enhance the ability to develop renewable resources and distributed generation

4. Pacific Power’s Smart Grid Strategy
Ensure that smart grid investments provide service at reasonable and fair prices by comparing products and solutions in a financial model to identify the most beneficial solutions
Institute cost-effective standards and equipment specifications that enable implementation of smart grid-compatible devices, either through retrofitting where appropriate or through replacement due to equipment obsolescence or failure
Provide customers with tools and understanding to change usage for their benefit
Leverage broad resources at our disposal including smart grid technology lessons learned across Berkshire Hathaway Energy’s four investor-owned utilities
Research industry projects and work with organizations to enhance Pacific Power’s understanding of smart grid technologies

5. Pacific Power’s Smart Grid Objective
Leverage smart grid technologies that optimize the electrical grid when and where it is economically feasible, operationally beneficial, and in the best interest of customers

6. The Cornerstone of Pacific Power’s 2016 Smart Grid Activities
Oregon Advanced Metering Infrastructure (AMI)
Pacific Power announced plans in April 2016 to install an AMI system in Oregon

7. Oregon AMI Overview
Pacific Power will deploy state of the art electronic digital hardware and software in a secure network that will capture interval data with continuously available two-way remote communications and control. AMI will also enable other business processes and transformations. A few initial benefits include:
System Operations Benefits
Improved network management – prevent transformer overloading
Improved network performance analytics – power quality and outage detection
Improved outage response and system planning
Improved integration of distributed generation
Financial and Environmental Benefits
Operating cost savings pay for investment
CO2 reduction from reduced truck rolls
Customer Service Benefits
Improved visibility of daily and hourly power consumption via a web portal
Improved billing accuracy

8. Positioning Customers for Long-Term Benefits
AMI provides a platform for Pacific Power to leverage future smart grid applications
AMI turns meters into sensors to the benefit of demand response, distribution automation, distributed energy resources and energy efficiency programs

9. Oregon AMI Project Timeline
Progress updates will be provided to the OPUC. First customer scheduled to go live by December 31st, 2017 and final customer transferred August 2019

10. Distribution Automation Deployment of equipment with progressive capability
Installed 40+ Fusesaver devices in Oregon resulting in reduced customer outages from temporary fault incidents
349 electronic reclosers (fault current indication) are distributed throughout Oregon service territory with the capability of retrofitting with communication modules
Evaluate recloser communications capability with AMI

11. Distribution Automation (continued)
Perform study of distribution automation potential in Oregon
Defined steps for preferred outcome
Determined criteria and requirements for location selection
For example: circuits with strong ties, existing SCADA, critical loads, etc.
Identified preliminary list of potential candidate sites
Comprehensive list of potential sites in Appendix H of the 2016 Report
Pilot project in Walla Walla, Washington
Investigate AMI integration with distribution automation
Respond to a questionnaire developed by the AMI network vendor to further investigate Distribution Automation integration with the AMI network

12. Transmission System Monitoring Dynamic Line Rating (DLR)
Sensors to monitor the conditions that impact the real-time temperature and loading ability of a transmission line
Assessment of West-of-Populus line project
Inconclusive due to low line-loading
Evaluation of thermal replicating relays (Soda Springs, Idaho area)
Remedial Action Scheme deemed more cost-effective
PacifiCorp transmission will continue to look for transmission constraints and other opportunities where dynamic line rating and/or thermal replicating relays may be viable solutions

13. Transmission System Monitoring Synchrophasors
The Steady-State and Dynamic System Model Validation Standard (NERC Reliability Standard MOD-033) is a new model validation standard proposed to establish consistent validation requirements to facilitate collecting accurate data and building of planning models to analyze the reliability of the interconnected transmission system
Compliance will facilitate improved system reliability
Locations were determined based on criteria in PRC-002 and are located throughout the Company’s service territory
Initial locations are provided in Appendix D of the 2016 Report
Deadline for compliance is July 1st, 2019

14. Distributed Energy Resources (DER) and Renewable Resource Enhancements
Potential use of DER to defer traditional solutions
DER Alternatives Template
Created through cross-platform effort with BHE
Applied to Redmond 5D22 circuit (Redmond, Oregon)
Traditional solution deemed cost-effective option

15. Distributed Energy Resources (DER) and Renewable Resource Enhancements (continued)
New standards and equipment specifications:
Regulator controls with bi-directional functionality
Pacific Power is participating in the re-draft of IEEE 1547 and will incorporate the final standard into company policies
IEEE 1547 addresses smart inverter requirements and how smart inverters support the stability, reliability and efficiency of the grid
Tentative release Q1 2018

16. Distributed Energy Resources (DER) and Renewable Resource Enhancements (continued)
Centralized Energy Storage - Oregon House Bill 2193
Pacific Power is working with the Commission on guidelines for the 5 MWh requirement
Areas under investigation include: infrastructure deferment, electric vehicle charging infrastructure, and other use cases
Propose project by 2018 and procure by 2020
Electric Vehicles - Oregon Senate Bill 1547
Pacific Power presented an overview of the proposal to stakeholders and solicited feedback for purpose of the program application
Finalize program filing before December 31, 2016
CYME – Engineering Distribution Analysis Software
Pacific Power fully installed CYME as of August 2016
CYME will be primary distribution planning tool starting January 2017
Pilot program for distribution substation metering
Identified initial locations in Bend and Hood River
Substation metering technical requirements are in Appendix G
Provides data to determine DER penetration levels

17. Demand Side Management Demand Response and Time-of-Use Pricing
Leveraged early lessons learned to increase participation to fulfill irrigation time-of-use (TOU) pilot allotment
Increased the potential for customer bill savings
Concentrated the pilot in a location where customers were more acutely aware of the cost of electricity
Conducted in-person outreach with the opportunity for potential participants to ask questions
Irrigation Load Control Pilot in Oregon
Approved by the Commission on
May 4, 2016
Successfully tested on August 29, 2016
Pacific Power provides a semi-annual
update to stakeholders

18. Smart Grid Timeline to 2020

19. Questions?