electric program investment charge (epic) 2017 annual report...electric program investment charge...

PACIFIC GAS AND ELECTRIC COMPANY

ELECTRIC PROGRAM INVESTMENT CHARGE (EPIC) 2017 ANNUAL REPORT

IN COMPLIANCE WITH CPUC DECISION 12-05-037

SUBMITTED FEBRUARY 28, 2018

VOLUME 1

ATTACHMENT A: 2017 Annual Report

ATTACHMENT B:

2017 Annual Report Appendix A

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PACIFIC GAS AND ELECTRIC COMPANY ATTACHMENT A

2017 EPIC ANNUAL REPORT

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ELECTRIC PROGRAM INVESTMENT CHARGE (EPIC)

2017 ANNUAL REPORT

FEBRUARY 28, 2018

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Pursuant to Decision (D.) 12-05-037 – Phase 2 Decision Establishing Purposes and Governance for Electric Program Investment Charge (EPIC) and Establishing Funding Collections for 2013-2020, Pacific Gas and Electric Company (PG&E) hereby files the 2017 Annual Report for the Electric Program Investment Charge Program.

In compliance with Ordering Paragraph 16, a copy will also be served on all parties in the most recent EPIC proceedings; the most recent general rate cases of PG&E, Southern California Edison Company (SCE), and San Diego Gas & Electric Company (SDG&E); and each successful and unsuccessful applicant for an EPIC funding award during the previous calendar year.

Service Lists -

EPIC 2012-2014: A.12-11-001, A.12-11-002, A.12-11-003, A.12-11-004,

EPIC 2015-2017: A.14-05-003, A.14-05-004, A.14-05-005, A.14-04-034

EPIC 2018-2020: A.17-04-028, A.17-05-003, A.17-05-005, 17-05-009

PG&E recently filed GRC: A.15-09-001,

SCE recently filed GRC: A.16-09-001,

SDG&E recently filed GRC: A.17-10-007

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Table of Contents

1. Executive Summary ........................................................................................................................... 8

a. Overview of Program and Highlights .......................................................................................... 8

b. Status of Programs .......................................................................................................................... 15

2. Introduction and Overview ................................................................................................................. 17

a. Background on EPIC ........................................................................................................................ 17

b. EPIC Program Components ............................................................................................................. 18

c. EPIC Program Regulatory Process ................................................................................................... 18

d. Coordination ................................................................................................................................... 18

e. Transparent and Public Process ...................................................................................................... 18

3. Budget ................................................................................................................................................. 19

a. Authorized Budget .......................................................................................................................... 19

b. Commitments/Encumbrances ........................................................................................................ 19

c. Dollars Spent on In-House Activities ............................................................................................... 20

d. Fund Shifting Above 5 Percent between Program Areas ................................................................ 20

e. Uncommitted/Unencumbered Funds ............................................................................................. 20

4 Projects ................................................................................................................................................ 21

a. Summary of Project Funding ........................................................................................................... 21

b. Project Status Report (See Appendix A).......................................................................................... 21

c. Project Descriptions and Updates ................................................................................................... 21

Project #1.01 – Energy Storage End Uses ........................................................................................... 22

Project #1.02 – Demonstrate the Use of Distributed Energy Storage for T&D Cost Reduction ......... 24

Project #1.03 – Demonstrate Priority Scenarios from the Energy Storage Framework ..................... 26

Project #1.04 – Expand Test Lab and Pilot Facilities for New Energy Storage Systems. ..................... 27

Project #1.05 – Demonstrate New Resource Forecast Methods to Better Predict Variable Resource

Output ................................................................................................................................................. 29

Project #1.06 – Demonstrate Communication Systems Allowing the CAISO to Utilize Available

Renewable Generation Flexibility ....................................................................................................... 31

Project #1.07 – Demonstrate Systems to Ramp Existing Gas-Fired Generation More Quickly to

Adapt to Changes in Variable Energy Resources Output .................................................................... 32

Project #1.08 – Improve Distribution System Safety and Reliability through New Data Analytics

Techniques .......................................................................................................................................... 34

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Project #1.09A – Test New Remote Monitoring and Control Systems for Existing Transmission and

Distribution Assets: Close Proximity Switching ................................................................................... 36

Project #1.09B and 1.10B – Test New Remote Monitoring and Control Systems for T&D Assets /

Demonstrate New Strategies and Technologies to Improve the Efficacy of Existing Maintenance and

Replacement Programs ....................................................................................................................... 38

Project #1.09C – Test New Remote Monitoring and Control Systems for T&D Assets: Discrete Series

Reactors .............................................................................................................................................. 40

Project #1.10A – Demonstrate Automated Asset Notification and Management Systems: Dissolved

Gas Analysis......................................................................................................................................... 42

Project #1.10C – Demonstrate Automated Asset Notification and Management Systems:

Underground Cable Analysis ............................................................................................................... 43

Project #1.11 – Demonstrate Self-Correcting Tools to Improve System Records and Operations .... 44

Project #1.12 – Demonstrate New Technologies that Improve Wildlife Safety and Protect Assets

from Weather-Related Degradation ................................................................................................... 46

Project #1.13 – Demonstrate New Communication Systems to Improve Substation Automation and

Interoperability ................................................................................................................................... 47

Project #1.14 – Demonstrate “Next Generation” SmartMeter™ Telecom Network Functionalities . 48

Project #1.15 – Demonstrate New Technologies and Strategies That Support Integrated “Customer-

to-Market-to-Grid” Operations of the Future .................................................................................... 50

Project #1.16 – Demonstrate Electric Vehicle as a Resource to Improve Grid Power Quality and

Reduce Customer Outages.................................................................................................................. 52

Project #1.17 – Leverage EPIC Funds by Participating in Multi-Utility, Industry Wide RD&D Programs

Such as EPRI ........................................................................................................................................ 54

Project #1.18 – Demonstrate SmartMeter™-Enabled Data Analytics to Provide Customers With

Appliance-Level Energy Use Information ............................................................................................ 56

Project #1.19 – Pilot Enhanced Data Techniques and Capabilities via the SmartMeter™ Platform .. 58

Project #1.20 – Demonstrate the Benefits of Providing the Competitive, Open Market With

Automated Access to Customer-Authorized SmartMeter™ Data to Drive Innovation. ..................... 60

Project #1.21 – Pilot Methods for Automatic Identification of Distributed Energy Resources (Such as

Solar PV) as They Interconnect to the Grid to Improve Safety & Reliability ...................................... 62

Project #1.22 – Demonstrate Subtractive Billing With Submetering for EVs to Increase Customer

Billing Flexibility .................................................................................................................................. 64

Project #1.23 – Demonstrate Additive Billing With Submetering for PVs to Increase Customer Billing

Flexibility ............................................................................................................................................. 66

Project #1.24 – Demonstrate Demand-Side Management (DSM) for Transmission and Distribution

(T&D) Cost Reduction .......................................................................................................................... 68

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Project #1.25 – Develop a Tool to Map the Preferred Locations for DC Fast Charging, Based on

Traffic Patterns and PG&E's Distribution System, to Address EV Drivers' Needs While Reducing the

Impact on PG&E's Distribution Grid .................................................................................................... 70

Project #1.26 – Pilot Measurement and Telemetry Strategies and Technologies That Enable the

Cost-Effective Integration of Mass Market Demand Response (DR) Resources into the CAISO

Wholesale Market ............................................................................................................................... 72

Project #2.01 – Evaluate Storage on the Distribution Grid ................................................................. 74

Project #2.02 – Pilot Distributed Energy Resource Management Systems (DERMS) ......................... 75

Project #2.03A – Test Smart Inverter Enhanced Capabilities – Photovoltaics (PV) ............................ 77

Project #2.03B – Test Smart Inverter Enhanced Capabilities – Vehicle to Home ............................... 79

Project #2.04 – DG Monitoring & Voltage Tracking ............................................................................ 81

Project #2.05 – Inertia Response Emulation for DG Impact Improvement ........................................ 83

Project #2.06 – Intelligent Universal Transformer (IUT) ..................................................................... 85

Project #2.07 – Real-Time Loading Data for Distribution Operations and Planning .......................... 87

Project #2.08 – “Smart” Monitoring and Analysis Tools ..................................................................... 89

Project #2.09 – Distributed Series Impedance (DSI) Phase 2.............................................................. 90

Project #2.10 – Emergency Preparedness Modeling .......................................................................... 91

Project #2.11 – New Mobile Technology & Visualization Applications .............................................. 93

Project #2.12 – New Emergency Management Mobile Applications ................................................. 94

Project #2.13 – Digital Substation/Substation Automation ................................................................ 95

Project #2.14 – Automatically Map Phasing Information ................................................................... 96

Project #2.15 – Synchrophasor Applications for Generator Dynamic Model Validation ................... 98

Project #2.16 – Enhanced Synchrophasor Analytics & Applications ................................................ 100

Project #2.17 – Geomagnetic Disturbance (GMD) Evaluation .......................................................... 101

Project #2.18 – Optical Instrument Transformers and Sensors for Protection and Control Systems

.......................................................................................................................................................... 102

Project #2.19 – Enable Distributed Demand-Side Strategies & Technologies .................................. 103

Project #2.20 – Real-Time Energy Usage Feedback to Customers ................................................... 105

Project #2.21 – Home Area Network (HAN) for Commercial Customers ......................................... 106

Project #2.22 – Demand Reduction Through Targeted Data Analytics ............................................ 108

Project #2.23 – Integrate Demand Side Approaches Into Utility Planning ....................................... 110

Project #2.24 – Appliance Level Bill Disaggregation for Non-Residential Customers ...................... 112

Project #2.25 – Enhanced Smart Grid Communications ................................................................... 113

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Project #2.26 – Customer & Distribution Automation Open Architecture Devices ......................... 114

Project #2.27 – Next Generation Integrated Smart Grid Network Management............................. 116

Project #2.28 – Smart Grid Communications Path Monitoring ........................................................ 118

Project #2.29 – Mobile Meter Applications ...................................................................................... 120

Project #2.30 – Leverage EPIC Funds to Participate in Industry-Wide RD&D Programs .................. 122

Project #2.31 – Aggregated Behind-The-Meter Storage Market / Retail Optimization ................... 123

Project #2.32 – Electric Load Management for Ridesharing Electrification ..................................... 124

Project #2.33 – Service Issue Identification Leveraging Momentary Outage Information ............... 125

Project #2.34 – Predictive Risk Identification with Radio Frequency (RF) Added to Line Sensors ... 126

Project #2.35 – Call Center Staffing Optimization ............................................................................ 128

Project #2.36 – Dynamic Rate Design Tool ....................................................................................... 129

5. Conclusion ..................................................................................................................................... 131

a. Key Results for the Year for PG&E EPIC Programs .................................................................... 131

b. Next Steps for EPIC Investment Plan ........................................................................................ 132

c. Issues That May Have Major Impact on Progress in Projects ................................................... 133

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1. Executive Summary

a. Overview of Program and Highlights

Pursuant to the California Public Utilities Commission (CPUC) Decision (D.) 12-05-037, Pacific Gas and Electric Company (PG&E) and the other Administrators of the Electric Program Investment Charge (EPIC) Program were directed to file annual reports each year beginning February 28, 2013 through February 28, 2020 with the Director of the CPUC’s Energy Division.1 Annual Reports shall be served on all parties in the most recent EPIC proceeding, all parties to the most recent general rate case of each electric utility, and to each successful and unsuccessful applicant for an EPIC funding award during the previous calendar year. In compliance with OP 16 of D.12-05-037, and consistent with the Annual Report outline developed collaboratively by the EPIC Administrators and the Office of Ratepayer Advocates,2 PG&E files its sixth annual report, documenting project activities since project inception through December 31, 2017.

In D.12-05-037, the Commission authorized funding in the areas of applied Research and Development (R&D), Technology Demonstration and Deployment (TD&D), and Market Facilitation. The Investor-Owned Utility (IOU) Administrators’ role was limited to TD&D only.

On November 19, 2013, the CPUC issued D.13-11-025, which authorized the first triennial investment period of 2012-2014 (referred to as EPIC 1). On April 15, 2015, the CPUC issued D.15-04-020, which approved the second triennial investment plan period of 2015-2017 (referred to as EPIC 2). On August 10, 2017, the CPUC issued Resolution E-4863, which approved two of the six new EPIC projects proposed by PG&E via a Tier 3 Advice Letter (AL) 5015-E filed on February 07, 2017, between triennial EPIC Applications as permitted by D.15-09-005. On April 28, 2017, PG&E filed its Application (A.) 17-04-028 for the third triennial investment plan period of 2018-2020 (referred to as EPIC 3). PG&E is currently waiting for CPUC decision and approval of this third triennial investment plan.

This report summarizes PG&E’s projects’ progress and status for the approved funding cycles, which includes TD&D projects in progress in the following areas:

1. Renewables and Distributed Energy Resource Integration – Integrate distributed energy resources, generation and storage; improve transparency of resource information; increase generation flexibility.

2. Grid Modernization and Optimization – Optimize existing grid assets; prepare for emerging technologies; design and demonstrate grid operations of the future.

3. Customer Service and Enablement – Drive customer service excellence through new offerings for PG&E’s customers that enable greater customer choice; integrate Demand-Side Management (DSM) for grid optimization.

1 The four EPIC Program Administrators are PG&E, SCE, SDG&E and the California Energy Commission (CEC).

2 This annual report outline is based on the adopted EPIC Administrator Annual Report Outline as described in Attachment 5 of D.13-11-025.

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4. Cross Cutting/Foundational Strategies and Technologies – Support next generation infrastructure, including smart grid architecture, cybersecurity, telecommunications and standards, as well as other “foundational” activities in support of all three program areas above.

PG&E continues to be strongly committed to the EPIC Program and the value it provides to the customers, as it offers the opportunity to cost-effectively develop and demonstrate innovative technologies which can advance the company’s core values of Safety, Reliability, and Affordability. Through these projects, the EPIC Program also contributes learnings that support important California clean energy policy goals, such as Greenhouse Gas (GHG) reduction goals and renewable energy targets.

Additionally, the main goals of EPIC align closely with PG&E’s Grid of Things™ strategy, which drives the advancement of innovative technologies that support PG&E’s core values and an evolving grid. The Grid of Things™ vision calls for the integration of new energy devices and technologies with the grid and, by virtue of their grid connectivity, allows PG&E customers to capture greater value from their energy technology investments, including rooftop solar, electric vehicles, energy storage, demand response technologies, and other such technologies. PG&E is the key builder and enabler of this interconnected and integrated platform that will continue to help define and shape California’s future energy landscape.

PG&E’s 2017 TD&D Program Highlights

PG&E is pleased to report the significant achievement of completing one EPIC 1 project and six EPIC 2 projects in 2017 and/or before filing the 2017 EPIC Annual Report, which brings the total number of completed EPIC 1 and 2 projects to date to twenty-two out of a total of thirty-six funded projects.

Below are the seven EPIC projects that have closed in 2017 and/or before filing the 2017 EPIC Annual Report:

1. EPIC 1.02 – Demonstrate the Use of Distributed Energy Storage for T&D Cost Reduction

2. EPIC 2.03B – Smart Inverter Enhanced Capabilities - Vehicle to Home

3. EPIC 2.04 – Distributed Generation (DG) Monitoring and Voltage Tracking

4. EPIC 2.19 – Enable Distributed Demand-Side Strategies & Technologies

5. EPIC 2.21 – Home Area Network (HAN) for Commercial Customers

6. EPIC 2.23 – Integrate demand side approaches into Utility Planning

7. EPIC 2.28 – Smart Grid Communications Path Monitoring

Each project’s purpose, methods, findings, results, and industry-relevant learnings are further documented in their individual final reports (attached in Appendices B through H).3

3 As specified in D.13-11-025 OP 14, Administrators must include with their EPIC annual report a final

report on projects completed during the previous year.

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Upon completion of these projects, PG&E will leverage learnings and may operationalize associated results, where applicable and cost-effective.

The results of PG&E’s technology demonstrations are also highly applicable to other industry stakeholders. For example, given the significant Distributed Energy Resource (DER) growth, the opportunities for utilities to partner with technology companies will continue to grow and be a key component of developing future capabilities. Utilities may apply learnings from EPIC 2.02 – Pilot Distributed Energy Resource Management Systems (DERMS) which is demonstrating a pre-commercial Distributed Energy Resource Management System (DERMS) to coordinate the control of various types of DERs, particularly third-party-aggregated Photovoltaic (PV) solar generation and battery energy storage resources. Development, testing and demonstration of DERMS will further California’s goals to adopt higher amounts of DERs on the grid, while providing operators with the necessary control mechanisms to operate the grid safely, reliably and effectively. An effective DERMS could integrate customer-sited Distributed Generation (DG) into grid operations to improve grid resiliency and reliability. It is important to note, however, that this technology is still in its early phases and therefore significant further development is needed before a commercial scale solution may be implemented. The DERMS demonstration will help to define future requirements for utility operating processes and systems, as well as for participating DERs.

In 2018, PG&E will continue to execute in-progress projects, including one EPIC 1 project and thirteen EPIC 2 projects. PG&E also plans to start execution on EPIC 3 projects subject to the timing of CPUC’s approval of PG&E’s EPIC 3 Application for the 2018-2020 program cycle.4

For detailed information on the developments and status of each EPIC 1 and EPIC 2 project, see Appendix A.

EPIC 1

In the first triennial cycle, the EPIC 1 portfolio demonstrated PG&E’s ability to adopt a new model for managing, aligning, tracking and executing research, development and demonstration (RD&D) activities. This portfolio covered a wide spectrum of technologies that help make the electric grid safer, more reliable and more affordable for customers. Some notable examples of EPIC 1 achievements in 2017 include:

• EPIC 1.01 – Energy Storage End Uses: This project successfully utilized PG&E’s Vaca-Dixon and Yerba Buena Battery Energy Storage Systems (BESS) to gain experience that addresses multiple barriers for utility-scale battery storage systems to participate in the California Independent System Operator’s (CAISO) Non-Generator Resource (NGR) market. PG&E developed and deployed an automated communications and control solution to fully utilize and evaluate BESS fast-response functionalities to determine their ability to instantaneously switch between different market products as the price of those products change. The project established input to processes for the operation of utility-scale battery storage resources as both market and distribution system assets, which may improve reliability and advance resilience by supporting PG&E customers in the event of a disturbance or outage. These results

4 A.17-04-028.

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have the potential to be leveraged by other electric utilities. The Association of Edison Illuminating Companies (AEIC) recognized and awarded PG&E the 2017 AEIC Achievement Award for EPIC Project 1.01. The award was granted in recognition of the significant contribution that work on this project has made toward advancing electric energy industry operations.

• EPIC 1.02 – Demonstrate the Use of Distributed Energy Storage for T&D Cost Reduction: This project demonstrated the ability of utility-owned and controlled energy storage resources to deliver autonomous distribution peak shaving functionality. Energy storage resources hold significant promise to help California address a variety of grid planning and operations challenges, both today and in the future. Energy storage resources have potential to advance Green House Gas (GHG) reduction goals and provide lower peak demand power costs for utility customers. The implementation and operational challenges associated with this project resulted in learnings that will inform PG&E’s procurement of future energy storage resources for grid support needs, both utility-owned and utility-contracted, through compliance with the IOU energy procurement targets as set forth in CPUC D.10-03-040 and beyond.

EPIC 2

The projects from EPIC 2 are even more focused on long-term strategic objectives and in many cases are built on the foundation of previous technology investments. Examples of this include analytics projects, such as EPIC 2.07 – Real Time Loading Data for Distribution Operations & Planning that uses data made available by the Advanced Metering Infrastructure (AMI) network to provide further grid insights for better projection of grid loading, and new use cases on how customer devices can support grid needs to continue to help enable the quickly emerging DER industry, such as through EPIC 2.19 – Enable Distributed Demand-Side Strategies & Technologies.

Additionally, in EPIC 2, PG&E further explored opportunities to leverage synergies between projects with similar objectives to drive the maximum benefit from the overall technology demonstration at the lowest possible cost to customers. As an example, when feasible, this approach can include sharing resources while also exploring the integration challenges of how the technologies may interact, which will become increasingly important in the future high-DER connected grid. PG&E has three projects that are being executed in parallel at a single distribution substation in San Jose to generate additional learnings from the interaction of these new technologies. EPIC 2.02 – Pilot Distributed Energy Resource Management Systems (DERMS) demonstrates a system that can monitor, optimize and dispatch utility-owned and behind-the-meter (BTM) DERs. This includes PV with Smart Inverters and Battery Storage devices, which PG&E is demonstrating through the following two projects respectively: EPIC 2.03A – Test Smart Inverter Enhanced Capabilities - Photovoltaics (PV) and EPIC 2.19 – Enable Distributed Demand-Side Strategies & Technologies. Coordinating these projects allows both PG&E and the larger industry to gain important new and novel learnings on the individual technologies, as well as how these technologies can work together to maintain a safe and reliable grid for utility customers. The grid of the future will not feature just one type of advanced technology, but a suite of technologies working in concert. These interrelated

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projects cost-effectively reinforce each other’s quality of learnings by testing multiple complementary technologies together.

In addition to the above highlights, some project-specific notable examples of EPIC 2 achievements in 2017 include:

• EPIC 2.02 – Pilot Distributed Energy Resource Management Systems (DERMS): The DERMS project successfully developed and deployed a cutting edge DERMS on three distribution feeders in San Jose and has been demonstrating seven use cases related to the impact and functionality of DERMS, including situational awareness about DER grid impacts, optimal dispatch of DERs to provide distribution services, and dual-use of DERs to provide distribution devices and enable market participation. Early results validate potential for DERs to provide distribution services and identify key DER requirements and utility investments in grid technology necessary to enable successful communications and dispatch instructions between the grid operator and DERs. Preliminary findings of the project indicate that DERs can successfully provide distribution services both voltage support and grid capacity; however, market participation of large DERs providing regulation complicates online power flow calculations and load forecasting efforts and will need to be addressed as market participation of DERs increases. As the dynamic, two-way operating environment develops, the DERMS project enables PG&E and other utilities to improve electric reliability and equip customers with valuable services and products that support their choices to adopt clean energy. In 2017, this project received the Greentech Media (GTM) Grid Edge Award5 and the Metering & Smart Energy International (MSEI) Innovation of the Year Award.6

• EPIC 2.23 – Integrate Demand Side Approaches into Utility Planning: This project successfully developed and demonstrated how a utility could integrate a broader range of customer-side technologies and DER approaches into the utility planning process. The project served as a necessary and enabling precursor to the fulfillment of Public Utility Code 769, which requires transparent, consistent and more accurate methods to cost-effectively integrate DERs into the distribution planning process. This project delivered new and more granular load shape profiles and enhanced load forecasting tools and overall analytical processes to allow PG&E to more accurately and consistently integrate DER impact into the distribution system load profile. With these enhancements, PG&E can more effectively assess the impact of DER growth on the timing and need for future distribution and transmission system upgrades. Any deferral of future distribution or transmission system upgrades would lower costs for electric ratepayers.

5 Greentech Media has presented the Grid Edge Award for the past 4 years to the leading companies

and projects that incorporate DERs and are re-envisioning the concept of centralized, unidirectional electricity delivery and overall addressing electricity management and delivery of the future. For 2017, the submission set was expanded to include international projects and companies, as well.

6 The MSEI award focuses on projects demonstrating the use of cutting-edge technology and critical thinking that are advancing utility systems into the 21st century.

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Some of PG&E’s achievements in EPIC 1 and 2 have also enabled PG&E to file four full patents and one provisional patent to date:

• EPIC 1.14 – Demonstrate “Next Generation” SmartMeter™ Telecom Network Functionalities: Patent for the development of the Smart Pole Meter

• EPIC 1.14 – Demonstrate “Next Generation” SmartMeter™ Telecom Network Functionalities: Patent for the development of the Smart Pole Meter Socket

• EPIC 1.14 – Demonstrate “Next Generation” SmartMeter™ Telecom Network Functionalities: Patent for an algorithm to help identify downed wires

• EPIC 1.21 – Pilot Methods for Automatic Identification of Distributed Energy Resources (Such as Solar PV) as They Interconnect to the Grid to Improve Safety & Reliability: Patent for an algorithm which can detect unauthorized PV interconnections

• EPIC 2.29 – Mobile Meter Applications: Provisional patent for the multi-purpose mobile meter (Next Generation Meter – NGM).

These patents may provide potential future revenue generating opportunities that would be shared with PG&E’s customers and shareholders,7 and ultimately support improved affordability if the patents lead to increased revenue. PG&E continues to consider opportunities to license patents, as well as opportunities to identify additional Intellectual Property in these and other projects.

Through the EPIC projects, PG&E has collaborated with national laboratories, universities, other utilities, third-parties, etc. Examples of collaboration include:

• EPIC 1.02 – Demonstrate Use of Distributed Energy Storage for Transmission and Distribution Cost Reduction: Early drafts of the BESS test protocols used in EPIC Project 1.02 were shared with the Electric Power Research Institute (EPRI) Energy Storage Integration Council and helped form the foundation for the now released EPRI Energy Storage Test Manual

• EPIC 1.22 – Demonstrate Subtractive Billing with Submetering for EVs to Increase Customer Billing Flexibility: In this project the joint IOU Administrators (PG&E, SDG&E and SCE) worked together to execute the project with the overall goal that various submetering scenarios be tested and integrated with the different IOU billing systems. Additionally, the project works with multiple EV Meter Data Management Agents (MDMAs) to test additional business models for submetering customer EV bills.

• EPIC 2.05 – Inertia Response Emulation for DG Impact Improvement: This project is currently working with the National Renewable Energy Laboratory (NREL) on equipment and hardware testing of inertia response. NREL is working with PG&E to develop recommendations on future synthetic inertia equipment performance requirements.

7 The revenue sharing mechanism is based on the guidance provided in CPUC D.13-110-25 OP 34,

which states “(IOUs) must apply a 75 percent/25 percent (ratepayer/shareholder) revenue sharing mechanism for net revenues (from future or ongoing royalties, license fees, and other “financial benefits of Intellectual Property (IP)”) related to financial benefits of IP that was developed under investor-owned utility contracts with Electric Program Investment Charge funds.”

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NREL’s unique ability to test equipment aligned well with the goals of this project to demonstrate the capability to emulate inertia injection and support primary frequency control using energy storage and smart inverter technologies to potentially mitigate the impacts of large-scale distributed generation to the grid.

• EPIC 2.29 – Mobile Meter Applications: The project worked with Lawrence Livermore National Lab (LLNL) who provided technical support for product development and demonstration of the mobile meter prototype.

In addition to the achievements highlighted above, it is equally important to recognize the value of EPIC in determining that a project is not ready to scale. The results of a number of EPIC projects found that more data, analysis, or technology advancement is necessary before the technology demonstrated is considered for adoption on a larger scale, which ultimately supports affordability for customers by not adopting the technology at scale before refinements are made to make the technology more viable. Below are examples of projects completed in 2017 with this outcome:

• EPIC 2.03B – Smart Inverter Enhanced Capabilities – Vehicle to Home: The project successfully demonstrated that a bi-directional EV and charger can support critical household loads through an outage. However, in addition to the technology not being commercially available, the project also determined that it is not cost effective for customers to adopt. This was supported by the project’s customer survey results, which indicate the current cost estimate is roughly four times higher than an optimal price for consumers. Therefore, even though the project use cases were technically proven, they are not currently viable due to technology cost, limited market value, and other restrictions between actors (e.g., EV battery warranty coverage).

• EPIC 2.04 – DG Monitoring & Voltage Tracking: This project successfully demonstrated an algorithmic process to analyze new data sources to predict the likelihood that an Electric Rule 2 voltage violation was caused by distributed solar generation. Solar energy is by nature intermittent, and ebbs and surges of generation can change the voltage for neighboring, downstream customers. As solar adoption continues to grow, there is an increased likelihood of such voltage violations. However, it was also clear through this project that integration with a larger grid analytics platform is needed for this algorithm to scale into operational use for use cases such as potential improved decision making for power quality engineers responding to customer issues and distribution planners as they work to support safe and reliable solar installation across PG&E’s service territory.

• EPIC 2.19 – Enable Distributed Demand-Side Strategies & Technologies: This project deployed customer-sited behind-the-meter (BTM) energy storage resources to demonstrate how these resources could support grid needs. This project successfully tested and demonstrated the use of customer-side BTM energy storage technologies to reduce peak loading and absorb DER generation in support of the electric grid and to promote affordability through potential distribution upgrade deferrals. The results of the project suggest that aggregated BTM customer energy storage could be leveraged in addressing capacity constraints with the utility customer benefit of both reliability and affordability. However, current vendor platforms for controlling customer-sited

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storage are not ready for utility operations, and communications to devices is not comparable to traditional utility communications. Addressing these issues, as well as considering the implementation of command prioritization for future multiple-use applications, are key next steps to creating scalable use of customer-sited BTM storage to address capacity constraints.

As an innovative and cost-effective way to explore technology demonstration projects, PG&E’s EPIC Program continues to form the foundational learnings that lead to opportunities to improve the safety, reliability and affordability of the electric grid, while increasing customer choice at the grid edge. These achievements help to prepare PG&E and the utility industry for upcoming challenges of a changing grid landscape.

b. Status of Programs

In D.13-11-025, the CPUC approved twenty seven of the twenty nine projects proposed by PG&E in the EPIC 1 Investment Plan, since two projects were formally withdrawn by PG&E prior to the issuance of this decision.8 In D.15-04-020, the Commission approved the thirty one projects proposed by PG&E in the EPIC 2 Plan.9 In Resolution E-4863, the Commission approved two of the six projects proposed by PG&E in the Tier 3 Advice Letter AL 5015-E filed between triennial EPIC Applications.10 On April 28, 2017, PG&E filed Application A.17-04-028 for the third triennial investment plan period of 2018-2020 (referred to as EPIC 3) which included forty-three proposed projects. PG&E is currently waiting for CPUC decision and approval of this third triennial investment plan.

PG&E has an internal governance structure intended to ensure that approved projects within the TD&D Program adhere to the EPIC guiding principles and requirements, as well as the potentially changing marketplaces and evolving technologies to ensure PG&E maximizes this program to continue to meet customer needs while maintaining safety, reliability, and affordability of the grid. PG&E may utilize remaining funds by either adding funding to active projects or further pursuing on-hold projects.

The following table summarizes the projects’ funding status by area and triennial investment plan program cycle as of December 31, 2017. (Note: This table does not include information on proposed EPIC 3 projects since they have not yet been approved by the CPUC).

8 In the EPIC 1 Plan Application (A.12-11-003), PG&E originally proposed 26 projects. Project 1.09

was subsequently split into three projects and project 1.10 was split into two projects resulting in a total of 29 projects. The projects formally withdrawn by PG&E were projects 1.04 and 1.07.

9 In the EPIC 2 Plan Application (A.14-05-003), PG&E originally proposed 30 projects. Per CPUC D.15-04-020 to include an assessment of the use and impact of EV energy flow capabilities, Project 2.3 was split into two projects, resulting in a total of 31 projects.

10 In the Tier 3 Advice Letter AL 5015-E filed between triennial EPIC applications, PG&E originally proposed 6 projects. CPUC Resolution E-4863 approved 2 (Projects 2.34 and 2.36) of the 6 proposed projects, allowed PG&E’s withdrawal of 1 project (Project 2.31), deferred 2 projects to a future investment plan (Projects 2.32 and 2.33) and rejected 1 project (Projects 2.35).

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Table1: Summary of Project Status and Funding by Program Cycle

EPIC Program Areas

EPIC 1 EPIC 2 Total

Ren

ewab

les

/ D

ER R

esou

rce

In

tegr

atio

n

Projects: 3 • 1.01 Energy Storage End Uses • 1.02 Demonstrate the Use of Distributed Energy Storage for T&D Cost Reduction • 1.05 Demonstrate New Resource Forecast Methods to Better Predict Variable

Resource Output *Committed Funding: $6.0M - $7.3M

Projects: 5 • 2.02 Pilot Distributed Energy Resource Management Systems • 2.03A Test Smart Inverter Enhanced Capabilities – PV • 2.03B Test Smart Inverter Enhanced Capabilities – Vehicle to Home • 2.04 DG monitoring & Voltage Tracking • 2.05 Inertia Response Emulation for DG impact improvement Committed Funding: $13.7M - $16.8M

Projects: 8 Committed Funding: $19.8M-$24.1M

Grid

M

oder

niza

tion

&

Opt

imiz

atio

n

Projects: 7 • 1.08 Improve Distribution System Safety & Reliability through New Data

Analytics Techniques • 1.09A Test New Remote Monitoring and Control Systems for Existing

Transmission & Distribution Assets: Close Proximity Switching • 1.09B/1.10B - Test New Remote Monitoring & Control System for T&D Assets

/ Demonstrate New Strategies and Tech to Improve the Efficacy of Existing Maintenance and Replacement Programs

• 1.09C Test New Remote Monitoring and Control Systems for T&D Assets: Discrete Series Reactors

• 1.14 Demonstrate “Next Generation” SmartMeter™ Telecom Network Function

• 1.15 Demonstrate New Technologies and Strategies That Support Integrated “Customer-to-Market-to-Grid” Operations of the Future

• 1.16 Demonstrate Electric Vehicle as a Resource to Improve Grid Power Quality and Reduce Customer Outages

Committed Funding: $16.1M - $19.7M

Projects: 5 • 2.07 Real Time Loading Data for Distribution Operations &

Planning • 2.10 Emergency Preparedness Modeling • 2.14 Automatically Map Phasing Information • 2.15 Synchrophasor Applications for Generator Dynamic Model

Validation • 2.34 Predictive Risk Identification with Radio Frequency (RF)

Added to Line Sensors Committed Funding: $10.4M-$12.7M


Cus

tom

er

Serv

ice

&

Enab

lem

ent

Projects: 7 • 1.18 Demonstrate SmartMeter™-Enabled Data Analytics to Provide Customers

With Appliance-Level Energy Use Information • 1.19 Pilot Enhanced Data Techniques and Capabilities via the SmartMeter™

Platform • 1.21 Pilot Methods for Automatic Identification of Distributed Energy

Resources (Such as Solar PV) as They Interconnect to the Grid to Improve Safety & Reliability

• 1.22 Demonstrate Subtractive Billing With Submetering for EVs to Increase Customer Billing Flexibility

• 1.23 Demonstrate Additive Billing With Submetering for PVs to Increase Customer Billing Flexibility

• 1.24 Demonstrate DSM for T&D Cost Reduction • 1.25 Develop a Tool to Map The Preferred Locations for DC Fast Charging,

Based on Traffic Patterns and PG&E's Distribution System, to Address EV Drivers' Needs While Reducing the Impact on PG&E's Distribution Grid

Committed Funding: $8.7M - $10.6M

Projects: 5 • 2.19 Enable Distributed Demand-Side Strategies & Technologies • 2.21 Home Area Network (HAN) for Commercial Customers • 2.22 Demand Reduction through Targeted Data Analytics • 2.23 Integrate Demand Side Approaches into Utility Planning • 2.36 Dynamic Rate Design Tool Committed Funding: $9.3M-$11.3M


Cro

ss-C

uttin

g/

Foun

datio

nal

Projects: 0 Committed Funding: $0M

Projects: 4 • 2.26 Customer & Distribution Automation Open Architecture Devices • 2.27 Next Generation Integrated Smart Grid Network Mgmt. • 2.28 Smart Grid Communications Path Monitoring • 2.29 Mobile Meter Applications

Committed Funding: $6.9M-$8.4M


Summary

Total Funded Projects: 17 Total Committed Funding: $30.8M-$37.7M Total Project Funding Encumbered: $22.8M Total Project Funding Spent to Date: $34.2M Total Administrative Costs Spent to Date: $2.5M

Total Funded Projects: 19 Total Committed Funding: $40.2M-$49.2M Total Project Funding Encumbered: $18.3M Total Project Funding Spent to Date: $28.0M Total Administrative Costs Spent to Date: 2.0M

Total Funded Projects: 36 Total Committed Funding: $71.1M-$86.9M Total Project Funding Encumbered: $41.1M Total Project Funding Spent to Date: $62.2M Total Administrative Costs Spent to Date: $4.5M

* Projects are prioritized through an internal governance process in order to manage committed funding. Remaining funds may, as needed, be redirected to other approved projects in order to efficiently utilize customer funds.

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2. Introduction and Overview

a. Background on EPIC

Funding for EPIC is authorized in Public Utilities Code (Pub. Util. Code) Section 399.8, which governed the Public Goods Charge (PGC) until expiration on January 1, 2012. The Commission opened an Order Instituting Rulemaking (R.11-10-003) to establish the Electric Program Investment Charge to preserve funding for the public ratepayer benefits associated with the renewables and RD&D activities provided by the electric PGC. The rulemaking included two phases, with Phase 1 to establish the EPIC Program on an interim basis in 2012, and Phase 2 to establish purposes and governance for EPIC to continue from 2013-2020.11 The EPIC Program Administrators include the CEC and three Electric IOUs: Pacific Gas and Electric (PG&E), Southern California Edison (SCE), and San Diego Gas and Electric (SDG&E).

In its Phase I Decision Establishing Interim Research, Development and Demonstrations and Renewables Program Funding Levels (D.11-12-035), the CPUC established 2012 funding at approximately $142 million and authorized PG&E, SCE and SDG&E to institute the EPIC Program, effective January 1, 2012, to collect funds for renewables programs, and RD&D programs at the same level authorized in 2011. Additionally, the surcharge was imposed on all distribution customers based on the existing rate allocation between customer classifications, and collected in the Public Purpose Program component of rates.

On May 24, 2012, the Commission issued its Phase 2 Decision Establishing Purposes and Governance for Electric Program Investment Charge and Establishing Funding Collections for 2013-2020. The decision established an annual funding amount of $162 million for the 2012-2014 EPIC Program cycle (EPIC 1) and set the funding allocations among the three IOUs

as 50.1 percent, 41.1 percent and 8.8 percent for PG&E, SCE and SDG&E, respectively.12 On April 15, 2015, the CPUC issued D.15-04-020, which approved the second triennial investment plan period of 2015-2017 (EPIC 2).

The EPIC Program is designed to assist the development of pre-commercialized, new and emerging clean energy technologies in California, while providing assistance to commercially viable projects. The goal of the EPIC Program is to support projects that help advance new technologies that further safety, reliability and affordability while advancing California’s clean energy goals, including Senate Bill 17 Smart Grid Goals and Public Utility. Code Section 740.1 goals focused on renewables integration and resource conservation, as well as GHG emissions reductions, economic development and low-emission vehicle and transportation support. EPIC supported activities are mapped to the different elements in the electricity-system value chain consisting of: Grid Operations/Market Design, Generation, Transmission, Distribution and Demand-Side Management.

11 See Phase 1 D.11-12-035 and Phase 2 D.12-05-037. 12 OP 7 of D.12-05-037 requires the total collection amount to be adjusted on January 1, 2015 and

January 1, 2018 commensurate with the average change in the Consumer Price Index for Urban Wage Earners and Clerical Workers for the third quarter, for the previous three years.

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b. EPIC Program Components

Authorized by D.12-05-037, the EPIC Program is to fund investments in the following three areas: (1) Applied Research and Development; (2) Technology Demonstration and Deployment (TD&D); and (3) Market Facilitation which consists of market research, regulatory permitting and streamlining, and workforce development activities. PG&E and the other IOU administrators were designated to administer EPIC funds only in the area of TD&D. The CEC was designated to administer funds in all areas, including a portion of TD&D.

c. EPIC Program Regulatory Process

The Phase 2 decision defines the regulatory process and governance for the EPIC Program. The decision requires EPIC Program Administrators to submit Triennial Investment Plans to cover three-year cycles for 2012-2014, 2015-2017, and 2018-2020. The investment plans must include details about planned investments, as well as criteria for selecting and evaluating proposals. Each plan must be evaluated and approved by the Commission prior to program implementation. To date, Administrators have filed three Triennial Investment Plans for 2012-2014, 2015-2017 and 2018-2020. PG&E is currently waiting for CPUC decision and approval of the IOUs’ third triennial investment plan period of 2018-2020 (EPIC 3). In addition to the Triennial Investment Plans, the Administrators are required to file Annual Reports each year on February 28 through 2020, as well as Final Reports for each project.

d. Coordination

In order to ensure adequate coordination of the EPIC Program, the EPIC Administrators continue to participate in regular review meetings, conduct joint webinars and workshops, and regularly collaborate on EPIC-related matters. The EPIC Administrators generally meet bi-weekly to discuss EPIC and their respective objectives for the program, as well as to ensure collaboration and avoid duplication.

The IOU Administrators also continue to work together to leverage consistent approaches, where feasible, for meeting the objectives of the EPIC Program. This collaboration resulted in the development of a common EPIC framework, approved by the Commission in D.13-11-025, to help guide the individual IOU investment plans.

e. Transparent and Public Process

The Program’s Administrators hold stakeholder workshops during the planning and implementation of the EPIC Triennial Investment Plans to ensure stakeholder feedback is received and incorporated. These stakeholder workshops to prepare for the Third Triennial Investment Plan were executed at the beginning of 2017 in advance of the EPIC 3 Application. Additionally, Administrators continue to engage with industry stakeholders by participating in and presenting at conferences, as well as hosting workshops/symposiums annually.

In 2017, EPIC Administrators jointly organized an EPIC 3 scoping workshop on February 3, 2017 at Sacramento, CA and two workshops for IOU-Focused EPIC 3 planning; one on March 9, 2017 in San Francisco, CA and the other on March 24, 2017 in Westminster, CA. EPIC Administrators also organized a Symposium on October 17, 2017 in San Diego, CA. The objective of the all-day symposium was to publicly showcase a variety of EPIC projects from the

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four administrators that support the symposium theme of Distribution System Automation. PG&E presented three projects: EPIC 2.14 – Automatically map phasing information, EPIC 2.22 – Demand Reduction through targeted data Analytics and 2.23 – Integrate demand side approaches into Utility Planning. These workshops and Symposium provided a mechanism to engage with industry stakeholders and bring transparency to the EPIC program and associated projects. Public notice for these events is provided to a broad range of stakeholders including technology vendors, researchers, academics and energy consultants. The utilities and the CEC will continue to maintain transparency in the process via webinars and workshops. Furthermore, PG&E’s EPIC Program continues to remain accessible to the interested public. PG&E’s EPIC website (www.pge.com/epic) includes EPIC Program information and updates, as well as EPIC annual reports and projects’ final reports.

3. Budget

a. Authorized Budget

The following table outlines the total Program, Administrative and CPUC regulatory oversight budget for each triennial cycle.

Table 2: Total Authorized Budget by Program Cycle

Total Authorized Budgets

PG&E Program Budget

(TD&D only)

PG&E Admin. Budget

(TD&D only)

CEC Program Budget* (TD&D,

Applied R&D, & Market

Facilitation)

CEC Admin Budget*

(TD&D, Applied R&D, & Market

Facilitation)

CPUC Regulatory Oversight

Budget

EPIC 1: 2012-2014 $43.3 Million

$4.9 Million

$166.2 Million $18.5 Million $1.2 Million

EPIC 2: 2015-2017 $45.7 Million

$5.1 Million

$182.9 Million $20.4 Million $1.3 Million

*portion remitted by PG&E

b. Commitments13/Encumbrances14

The following table outlines the PG&E total financial commitments and encumbrances, as well the remittances made to both the CEC and CPUC beginning from program inception through December 31, 2017.

13 Per CPUC D. 13-11-025, “committed funds” are monies budgeted for a particular project. The

committed fund range is defined as project approved through PG&E’s internal governance process. 14 Per CPUC D. 13-11-025, “encumbered funds” refer to monies specified within contracts signed

during a previous triennial investment plan cycle and associated with specific activities under that contract.

http://www.pge.com/epic

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Table 3: Total Commitments/Encumbrances by Program Cycle

Commitments / Encumbrances

PG&E Total Commitments

PG&E Total Encumbrances

CEC Program Remittance

CEC Admin Remittance

CPUC Remittance

EPIC 1: 2012-2014 $30.8 - $37.7 Million $22.8 Million $166.2 Million $18.5 Million $1.2 Million

EPIC 2: 2015-2017 $40.2 - $45.7 Million $18.3 Million $100.2

Million $20.4 Million $1.3 Million

c. Dollars Spent on In-House Activities

The following table outlines the PG&E total in-house project expenditures and administrative costs, beginning from program inception through December 31, 2017.

Table 4: Total Dollars Spent on In-House Activities by Program Cycle

Program Cycle PG&E In-House TD&D Project Expenditures *

PG&E In-House Program Administrative Costs

EPIC 1: 2012-2014 $11.6 Million

$1.4 Million

EPIC 2: 2015-2017 $11.5 Million

$1.9 Million

*PG&E In-House TD&D Project Expenditure includes internal staffing and staff augmentation at the project level.

d. Fund Shifting Above 5 Percent between Program Areas

All PG&E projects are within TD&D; therefore, there has been no fund shifting between program areas.

e. Uncommitted/Unencumbered Funds15

Projects without committed funding are pending further project and benefits analysis. The range of uncommitted funds is dependent on the range of authorized budget and committed funds as identified in Sections 3a and 3b, respectively. The following table outlines the PG&E uncommitted/unencumbered funding for each program cycle as of December 31, 2017.

15 “Uncommitted” and “Unencumbered” funds refer to monies that are not identified in solicitation plans

or obligated to a particular project—these funds are considered unspent.

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Table 5: Total Uncommitted/Unencumbered Funds by Program Cycle Program Cycle Uncommitted/Unencumbered

Project Funds

EPIC 1: 2012-2014 $5.7 - $12.5 Million

EPIC 2: 2015-2017 $0 - $5.5 Million

4 Projects

a. Summary of Project Funding

For a summary of project funding please refer to Table 1 in Section 1b.

b. Project Status Report (See Appendix A)

See Project Status Report, Appendix A, with project details as of December 31, 2017. The Project Status Report is based on the format provided in Attachment 6 of D.13-11-025.

c. Project Descriptions and Updates

The project descriptions and updates included below are for both EPIC 1 and EPIC 2 projects as of December 31, 2017. Projects that are on-hold have been included in the summary.

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Project #1.01 – Energy Storage End Uses

i. Investment Plan Period

• 1st Triennial (2012-2014) ii. Assignment to Value Chain

• Grid Operation/Market Design iii. Objective

• Develop technologies and strategies for efficient and optimized bidding and scheduling of Energy Storage Technologies (EST) in California Independent System Operator (CAISO) markets and demonstrate those strategies using PG&E’s existing Sodium Sulfur Battery Energy Storage Systems (NaS BESS).

• This project addresses the following CPUC proceedings: ▪ As applicable, operational experiences gained from this project can inform

outstanding policy and implementation issues as identified in Energy Storage Order Instituting Rulemaking 15-03-011.

iv. Scope

• Develop and deploy technology to enable automated resource response to CAISO market awards.

• Quantify the values that battery resources can capture in CAISO markets.

• Establish financial performance of battery resource participation in CAISO markets. v. Deliverables

• Demonstrate automated and remote-control application for generic energy storage resources to interface with existing Supervisory Control and Data Acquisition systems.

• Report financial performance from participation in CAISO markets.

• Report comparison of actual performance vs. hypothetical performance quoted in industry reports.

• Comply with regulatory requirements and establish framework/recommendations for accounting standards applicable to energy storage.

vi. Metrics

• 1i – Nameplate capacity (megawatts) of grid-connected energy storage.

• 3a – Maintain/Reduce operations and maintenance costs.

• 6a – CAISO NGR financial settlements.

• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid (Public Utilities Code (Pub. Util. Code) § 8360).

• 7c – Dynamic optimization of grid operations and resources, including appropriate consideration for asset management and utilization of related grid operations and resources, with cost-effective full cyber security (Pub. Util. Code § 8360).

• 7l – Identification and lowering of unreasonable or unnecessary barriers to adoption of smart grid technologies, practices, and services (Pub. Util. Code § 8360).

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• 9c – EPIC project results referenced in regulatory proceedings and policy reports (Business Plan references: CPUC R.10-12-007).

vii. Schedule

• 2.75 years viii. EPIC Funds Encumbered

• $616,857 ix. EPIC Funds Spent

• $1,833,968 x. Partners (if applicable)

• N/A xi. Match Funding (if applicable)

• N/A xii. Match Funding Split (if applicable)

• N/A xiii. Funding Mechanism (if applicable)

• Pay for performance xiv. Treatment of Intellectual Property (if applicable)

• N/A xv. Status Update

• Project completed in 2016.

• Final Report was included in 2016 EPIC Annual Report.

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Project #1.02 – Demonstrate the Use of Distributed Energy Storage for T&D Cost Reduction



• Distribution; Grid Operation/Market Design iii. Objective

• Demonstrate the ability of a utility operated energy storage asset to address capacity overloads on the distribution system and improve reliability.

• This project addresses the following California Public Utilities Commission (CPUC) proceedings:

• This project will count towards the Investor-Owned Utility energy procurement targets as set forth in D.10-03-040, the Energy Storage Procurement Framework.

• As applicable, operational experiences gained from this project can inform outstanding policy and implementation issues as identified in Energy Storage OIR R.15-03-011.

iv. Scope

• Deploy utility operated energy storage asset at a single site.

• Demonstrate peak shaving use case along with other site-specific use cases as suggested by distribution operators.

v. Deliverables

• Identify energy storage site based on project objectives.

• Identify an economic modeling tool to compare the planned traditional utility with alternatives using distributed resources or demand-side investments.

• Construct and integrate energy storage system.

• Test system and analyze results to prove project objectives. vi. Metrics

• 1c – Avoided procurement and generation costs.


• 7d – Deployment and integration of cost-effective distributed resources and generation, including renewable resources (Pub. Util. Code § 8360).

• 9c – EPIC project results referenced in regulatory proceedings and policy reports (Business Plan references: Deferring a capacity upgrade has been identified as a key potential value of Energy Storage Technologies (ESTs) and noted in filings with the CPUC/Assembly Bill 2514.

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vii. Schedule


• $2,686,621 ix. EPIC Funds Spent



• No xii. Match Funding Split (if applicable)


• Pay for Performance xiv. Treatment of Intellectual Property (if applicable)

• N/A xv. 2017 Status Update

• Project completed in February 2018

• This project demonstrated the ability of utility-owned and controlled energy storage resources to deliver autonomous distribution peak shaving functionality.

• Energy storage resources hold significant promise to help California address a variety of grid planning and operations challenges, both today and in the future. The implementation and operational challenges associated with this project resulted in learnings that will inform PG&E’s procurement of future energy storage resources, both utility-owned and utility-contracted, through compliance with the IOU energy procurement targets as set forth in CPUC D. 10-03-040 and beyond.

• Final Report included in this 2017 EPIC Annual Report

26

Project #1.03 – Demonstrate Priority Scenarios from the Energy Storage Framework




• The project aims to reduce existing barriers to deployment of battery energy storage systems by demonstrating whether post-electric vehicle (EV) “second life” batteries can cost-effectively perform electric distribution services. The project will demonstrate the potential for reduced energy storage system costs via a) the development of an integration platform for deploying such batteries (Phase 1) and b) the use of lower cost “second life” batteries in the integrated platform (Phase 2).

iv. Scope

• Project scope being further evaluated - TBD v. Deliverables

• Project deliverables being further evaluated - TBD vi. Metrics

• TBD vii. Schedule

• Project schedule being further evaluated - TBD viii. EPIC Funds Encumbered

• $0 ix. EPIC Funds Spent

• $0 x. Partners (if applicable)

• TBD xi. Match Funding (if applicable)

• TBD xii. Match Funding Split (if applicable)

• TBD xiii. Funding Mechanism (if applicable)

• TBD xiv. Treatment of Intellectual Property (if applicable)

• TBD xv. Status Update

• Project is currently on-hold.

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Project #1.04 – Expand Test Lab and Pilot Facilities for New Energy Storage Systems.



• Grid operations/market design iii. Objective

• This project would identify ways to enhance the existing test lab facilities at PG&E’s Applied Technology Services (ATS) center to provide lab test and pilot facilities for new energy storage systems not previously lab tested. PG&E’s ATS lab will be particularly helpful in working with the CEC and industry to test “next generation” technologies that have the potential to make breakthroughs in cost, performance targets, and other important parameters, in a test grid environment. This testing would be a critical step in accelerating commercialization of potential “game changing” technology. New types of technology that may be tested at ATS include, but are not limited to, advanced lithium devices, new sodium-based systems, zinc-air systems and new flow battery chemistries and formats. The funding required to add full capabilities to ATS is minimal. The costs to perform the tests will be paid by the industry or by entities that have received research grants from agencies such as the CEC or Department of Energy (DOE).

iv. Scope

• N/A v. Deliverables

• N/A vi. Metrics

• N/A vii. Schedule

• N/A viii. EPIC Funds Encumbered

• N/A ix. EPIC Funds Spent

• N/A x. Partners (if applicable)




• N/A

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xiv. Treatment of Intellectual Property (if applicable)


• Formally Withdrawn. CPUC A.12-11-003, 10/15/2013.

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Project #1.05 – Demonstrate New Resource Forecast Methods to Better Predict Variable Resource Output



• Distribution iii. Objective

• Demonstration of emerging capabilities in mesoscale modeling to provide more granular and accurate weather forecasting input to Pacific Gas and Electric Company’s (PG&E) storm damage prediction model, and to other PG&E forecasting applications, like catastrophic wildfire risk and Photovoltaic (PV) generation. The main goal is more effective and granular damage prediction, and therefore more efficient response to storm events.

iv. Scope

• Project focus is on development, deployment, and implementation of an operational version of the Weather Research and Forecasting (WRF) mesoscale model to support PG&E’s forecasting program related to fire, storms and solar production.

• Not in scope for this project are enhancements to PG&E’s Restoration Work Plan other than improved forecast damage numbers.

v. Deliverables

• Fully functional mesoscale modeling system known as POMMS (PG&E Operational Mesoscale Modeling System) that will provide the following:

▪ Detailed weather input into PG&E’s damage prediction modeling system (SOPP). ▪ Next generation wildfire threat awareness system. ▪ Historical and forecast solar irradiance data to internal PG&E stakeholders.

vi. Metrics


• 4a – GHG emissions reductions (MMTCO2e).

• 5c – Forecast accuracy improvement.

• 5e – Utility worker safety improvement and hazard exposure reduction. vii. Schedule



• $823,890 x. Partners (if applicable)

• N/A

30

xi. Match Funding (if applicable)




• N/A

xv. Status Update



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Project #1.06 – Demonstrate Communication Systems Allowing the CAISO to Utilize Available Renewable Generation Flexibility




• This project would demonstrate the use of accepted communications protocols to allow the California Independent System Operator (CAISO) to send an operating signal to reduce output under specified conditions, as allowed by contracts.

iv. Scope

• Project scope being further evaluated – TBD v. Deliverables

• Project deliverables being further evaluated – TBD vi. Metrics








• N/A xiv. Treatment of Intellectual Property (if applicable)



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Project #1.07 – Demonstrate Systems to Ramp Existing Gas-Fired Generation More Quickly to Adapt to Changes in Variable Energy Resources Output



• Grid operations/market design iii. Objective

• There are 33 General Electric 7FA gas turbines installed in combined cycle configurations in California, which is considerably more than any other turbine model. GE offers a product marketed as “OpFlex Balance” that uses advanced controls technology to improve ramp rates to as high as 40 MW per minute (or higher in some cases). As of October 2012, none of the 7FAs in California were using this product. This project proposes to demonstrate improved ramp rate capabilities on one 7FA so that it can serve as a model for the rest of the 7FA fleet. It is assumed that there would be cost share with the vendor and the selected plant owner.

iv. Scope


• N/A vi. Metrics









• N/A

33

xv. Status Update

• Formally Withdrawn CPUC A.12-11-003, 10/15/2013

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Project #1.08 – Improve Distribution System Safety and Reliability through New Data Analytics Techniques



• Transmission; Distribution iii. Objective

• Develop and demonstrate a new data analytics technique to improve distribution system safety and reliability. The project specifically developed and tested a System Tool for Asset Risk (STAR), which is an enterprise software application that Electric Operations will use to calculate and display (graphically and geospatially) risk scores for electric transmission, substation and distribution assets. The STAR will enable an automated, system-wide application to improve risk identification, prioritization, and investment decisions to support electric system safety.

iv. Scope

• Demonstrate whether the ever-increasing amounts of data can be mined and combined for targeted, cost-effective use for improved asset management.

• Potential scenarios include risk-based asset management, safety hazard mitigation and proactive outage prediction using self-serve and virtual integration environments.

v. Deliverables

• Overview of existing applications and data sources.

• Assessment of existing data source quality.

• High-level future business processes by functional area.

• Inventory of asset risk algorithms (formulas or complexity) for “In Scope” asset classes.

• High-level Change Management Approach.

• Prioritized and phased implementation plan.

• Cost estimate for full implementation of the STAR project.

• Proof of concept prototype. vi. Metrics

• 7c – Dynamic optimization of grid operations and resources; including appropriate consideration for asset management and utilization of related grid operations and resource, with cost-effective full cyber security (Public Utilities Code §8360).

• 3a – Maintain/Reduce operations and maintenance costs: With the improved understanding of risk, there could be a better tool for evaluating projects such as asset replacement.

vii. Schedule


• $1,249,505

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ix. EPIC Funds Spent








• Final report included in 2015 EPIC Annual Report.

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Project #1.09A – Test New Remote Monitoring and Control Systems for Existing Transmission and Distribution Assets: Close Proximity Switching




• This project explores and seeks to discover effective, new tools to safely operate “Solid Blade in Oil Rotatory Switches.”

iv. Scope

• Test new tools and techniques for safe operation of Solid Blade in Oil Rotatory Switches.

• Evaluate alternatives to decrease probability of injury to workers and public.

• Help design a robotic tool to allow remote operation.

• Develop the necessary parts/adaptors to be used on various types (manufacturer, brand, age, etc.) of Solid Blade in Oil Rotatory Switches.

v. Deliverables

• A working prototype for various Solid Blades in Oil Rotatory Switch tools. vi. Metrics

• 5a – Outage number, frequency and duration reductions.









• N/A

37

xv. Status Update



38

Project #1.09B and 1.10B – Test New Remote Monitoring and Control Systems for T&D Assets / Demonstrate New Strategies and Technologies to Improve the Efficacy of Existing Maintenance and Replacement Programs




• The project focus is on development, testing, deployment, and implementation of new technologies, construction methods and techniques, and cost reduction techniques in support of the Supervisory Control and Data Acquisition (SCADA) monitoring systems used on the Distribution Networks. The monitoring system consists of a complex and extensive set of components used to assess the health and condition of the network transformers on a continuous basis. This research is looking at potential failure points on the monitoring system components and what technologies and improvements can be applied to increase life expectancy of these components and reduce production and maintenance costs for this system and similar systems.

iv. Scope

• Assess new technologies and feasibility of application on the Distribution Networks.

• Primary focus on technologies, components and work methods to extend the life expectancy of monitoring systems equipment and reduce long term maintenance costs.

v. Deliverables

• Modified or improved components identified for use on Distribution Network Monitoring System.

• Improved installation and construction work methods.

• Economic model for maintenance variables based on life expectancy testing of components.

• Changes to components. vi. Metrics


• 3b – Maintain/Reduce capital costs.

• 5d – Public safety improvement and hazard exposure reduction.



• $484,250

39










40

Project #1.09C – Test New Remote Monitoring and Control Systems for T&D Assets: Discrete Series Reactors



• Transmission iii. Objective

• Gain operating experience with Discrete Series Reactors (DSR) to determine whether such devices would be cost effective and operate reliably and safely on Pacific Gas and Electric Company’s (PG&E) transmission system.

iv. Scope

• Install and test 90 DSR units on the Las Positas-Newark 230 kV line.

• Install and test Server at PG&E’s San Francisco General Office (SFGO) headquarters, complete with Smart Wire System Manager Software.

• Communication links between the DSRs and server to support the DSR monitoring and control.

v. Deliverables

• Installation, testing and analysis of DSR and server communication links.

• Procure, construct and test the DSRs.

• White paper describing project including go/no go recommendation.

• Final report describing overall project, including finding from the operations and testing of DSR units and a recommendation as to whether or not to install the DSRs elsewhere in the PG&E system.

vi. Metrics




• 5b – Electric system power flow congestion reduction. vii. Schedule




• N/A

41








42

Project #1.10A – Demonstrate Automated Asset Notification and Management Systems: Dissolved Gas Analysis




• Develop tools and algorithms that analyze data from monitoring equipment installed on substation equipment (distribution and transmission) that tests for dissolved gasses or other precursor data that would assist in understanding the condition of the equipment.

iv. Scope













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Project #1.10C – Demonstrate Automated Asset Notification and Management Systems: Underground Cable Analysis




• Develop tools and algorithms that analyze load and operating characteristic data from underground cables in order to develop an understanding of potential failure points, cable maintenance needs, and cable life expectancy.

iv. Scope













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Project #1.11 – Demonstrate Self-Correcting Tools to Improve System Records and Operations




• Demonstrate tools that identify and “register” existing assets to improve the integration between utility planning and operations. As part of the demonstration, implement “self-correcting” technologies that identifies plan vs. actual discrepancies and updates system records automatically.

• High priority use cases include: (1) Mapping of transformers to primary phase; (2) Mapping of customers to transformers; and (3) Precision mapping of Pacific Gas and Electric Company’s overhead and underground network.

iv. Scope










• TBD

45




46

Project #1.12 – Demonstrate New Technologies that Improve Wildlife Safety and Protect Assets from Weather-Related Degradation




• Demonstrate new strategies and technologies to improve animal and bird protection, reduce outages caused by animals and birds, and protect assets from expensive weather-related degradation such as fog-related corrosion.

iv. Scope

• Project scope being further evaluated – TBD v. Deliverables

• Project deliverables being further evaluated – TBD vi. Metrics


• Project schedule being further evaluated – TBD viii. EPIC Funds Encumbered









47

Project #1.13 – Demonstrate New Communication Systems to Improve Substation Automation and Interoperability




• Demonstrate new strategies and technologies to convert and integrate multiple existing proprietary technologies within the substation environment for more effective operations. Substation are key operational hubs and represent significant investments, which must be further leveraged by engaging with vendors to create the next generation of interoperable substation services and products.

iv. Scope













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Project #1.14 – Demonstrate “Next Generation” SmartMeter™ Telecom Network Functionalities



• Distribution; Grid Operation/Market Design; Demand-Side Management iii. Objective

• This project explores and discovers effective new network applications and devices to leverage and improve the SmartMeter™ communications network.

iv. Scope

• Leverage the existing SmartMeter™ network to support additional applications. Inform future uses of the SmartMeter™ network such as message capability, security, latency, and engineering constraints. Specifically focus on:

▪ Test new devices to support network functions and capabilities not previously envisioned (e.g., new data streams, faster data collection).

▪ Evaluate alternatives to decrease future upgrade, maintenance and/or operational costs.

▪ Demonstrate different network applications, each focused on separate use cases.

v. Deliverables

• Evaluate new applications and devices, their associated data traffic impact on the SmartMeter™ network, and recommend which items warrant consideration for full-scale deployment.

• Develop business case based on findings for full deployment consideration. vi. Metrics

• 7f – Deployment of cost-effective smart technologies, including real time, automated, interactive technologies that optimize the physical operation of appliance and consumer devices for metering, communications concerning grid operations and status, and distribution automation (Public Utilities Code (Pub. Util. Code) §8360).

• 7k – Develop standards for communication and interoperability of appliances and equipment connected to the electric grid, including the infrastructure serving the grid (Pub. Util. Code §8360).

• Note: Each technology demonstrated may have additional specific benefits to name. For instance, the following could apply: improved communication for power restoration, improved control of streetlights, etc.

vii. Schedule

• 3.25 years

49

viii. EPIC Funds Encumbered







• Patents filed for – ▪ Smart Pole Meter ▪ Smart Pole Meter Socket and ▪ An algorithm to help identify downed wires

xv. Status Update



50

Project #1.15 – Demonstrate New Technologies and Strategies That Support Integrated “Customer-to-Market-to-Grid” Operations of the Future




• The objective of this pilot is to develop and pilot a real-time data visualization software platform for use by Electric Distribution Operations end users. Data will be integrated from various data sources and displayed on Distribution Control Center video walls and individual desktop computers, with potential for future scalability to handheld devices.

iv. Scope

• Scope includes the integration of data (network model, loading, SmartMeter™ devices, outages, weather, etc.) and a real-time data visualization platform for Distribution Operations.

• The Distribution Management System (DMS) platform and predictive analytics are not included in the scope.

v. Deliverables

• Demonstrate Real-time Data Visualization Platform, including data integration from a variety of data sources and a visual interface that includes geospatial, list, and trending layers.

vi. Metrics


• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security and efficiency of the electric grid (Public Utilities Code 8360).

• 3a – Maintain/Reduce operations and maintenance costs. vii. Schedule






• N/A

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xiii. Funding Mechanism (if applicable)


• Intellectual Property (IP) has been created through co-development with the vendor. PG&E retains ownership rights to the IP and will provide free unlimited use rights to California Investor-Owned Utilities per the California Public Utilities Commission decision

xv. Status Update



52

Project #1.16 – Demonstrate Electric Vehicle as a Resource to Improve Grid Power Quality and Reduce Customer Outages




• Leverage plug-in hybrid vehicle technology emerging in Pacific Gas and Electric Company (PG&E) fleet to generate utility-grade power, supporting distribution circuits during planned or unplanned outage events.

iv. Scope

• Develop nominally 120 kilowatt exportable power capabilities from a plug-in hybrid electric truck. Seek to create the protocols necessary to safely connect the truck to the appropriate grid connection points. The portfolio of fleet vehicles (higher and lower weight classes) may broaden the range of available power ratings demonstrated by the project.

v. Deliverables

• Develop operating requirements for the vehicle.

• Understand engineering challenges with high power export with collaborative supplier development to solve.

• Develop safety and interconnection protocols to connect the vehicle to the grid leveraging existing protocols for temporary local generator set connection.

• Define and document power requirements for different outage/usage scenarios.

• Develop operating protocols (when and how the vehicles will be used).

• Develop unplanned outage protocols.

• Develop the hardware and software (if required) to connect the vehicle to PG&E’s system.

• Build vehicles for field testing. vi. Metrics


• 5e – Utility worker safety improvement and hazard exposure reduction.


• 4a – Greenhouse Gas emissions reductions (MMTCO2e). vii. Schedule


• $1,688,840

53



• Department of Energy/National Renewable Energy Laboratory; Edison Electric Institute engaged for elec. utility industry staging events; Portland General Electric closely collaborating for industry-level requirements








54

Project #1.17 – Leverage EPIC Funds by Participating in Multi-Utility, Industry Wide RD&D Programs Such as EPRI




• PG&E can leverage EPIC dollars by participating and collaborating in multi-utility industry-wide research initiatives conducted by third party organizations experienced in the RD&D area. These programs would allow PG&E to cost effectively develop a deeper awareness of industry trends, access real world experience through pilot programs, and identify the gaps that utilities will fill or close with technology. For example, through participation in existing EPRI programs, PG&E would participate in and gain access to demonstrations, analyses, and results of the testing and study of distribution equipment and strategies. High Value EPRI programs include: IntelliGrid, Integration of Distributed Renewables, Energy Storage, Risk Mitigation Strategies, and Distribution Grid Modernization programs.

iv. Scope










• TBD

55




56

Project #1.18 – Demonstrate SmartMeter™-Enabled Data Analytics to Provide Customers With Appliance-Level Energy Use Information



• Demand-Side Management iii. Objective

• This project focuses on delivering the cost by major appliances to customers. iv. Scope

• This project will use the data enabled by the SmartMeter™ platform to provide appliance-level itemization of monthly bill charges to customers, without their completing any audit or subscribing to any new service. This project assumes that minute level meter data is available.

v. Deliverables

• Quantify disaggregation accuracy and compare vendors.

• Based on results, provide recommendations for deployment strategy of appliance-level billing.

vi. Metrics

• 1f – Avoided customer energy use.

• 1h – Customer bill savings (dollars saved). vii. Schedule








• N/A

57

xv. Status Update



58

Project #1.19 – Pilot Enhanced Data Techniques and Capabilities via the SmartMeter™ Platform




• The project is to explore and discover effective, new data that can be collected and studied for further benefits. Demonstrate the type of additional data that can be collected and/or processed through the SmartMeter™ platform. Evaluate impact of any increased data traffic on the SmartMeter™ network. Focus on new data collection that makes the SmartMeter™ platform more robust for more customers.

iv. Scope

• Demonstrate the collection of new data from SmartMeter™ devices. Example use cases include:

▪ Power Quality Data (C12.19 format). ▪ New Data Channels. ▪ Mobile data collection methods. ▪ Power theft detection methodology using SmartMeter™ data for revenue

assurance purposes. v. Deliverables

• Evaluate new data and analytic methodologies, their associated impact on the SmartMeter™.

• Recommendation of which data warrants consideration for full-scale deployment.

• Evaluation should provide key inputs to a business case for general deployment. vi. Metrics

• 1h – Customer bill savings (dollars saved).

• 1f – Avoided customer energy use (kilowatt-hours saved).





• 5f – Reduced flicker and other power quality differences.

• 5i. – Increase in the number of nodes in the power system at monitoring points.

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• 7f – Deployment of cost-effective smart technologies, including real time, automated, interactive technologies that optimize the physical operation of appliance and consumer devices for metering, communications concerning grid operations and status, and distribution automation.

• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security and efficiency of the electric grid.

vii. Schedule











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Project #1.20 – Demonstrate the Benefits of Providing the Competitive, Open Market With Automated Access to Customer-Authorized SmartMeter™ Data to Drive Innovation.



• Customer Service and Enablement iii. Objective

• This project will fund continued support of Green Button Connect (GBC). GBC provides a small number of vendors in the competitive market with automated access to recurring, machine-to-machine, programmatic data access to customer-authorized SmartMeter™ data in order to develop new, innovative and creative ways for customers to manage their energy consumption. GBC is a small demonstration, not scalable to support the larger customer base and wider vendor audience. PG&E is planning on implementing a robust, broader scale offering as part of its Customer Data Access (CDA) project.

iv. Scope


• N/A vi. Metrics









• N/A

61

xv. Status Update

• Formally notified CPUC on 10-31-13, project may be terminated as refined scope does not appear to meet safety, reliability, affordability guiding principles for priority Research and Development.

62

Project #1.21 – Pilot Methods for Automatic Identification of Distributed Energy Resources (Such as Solar PV) as They Interconnect to the Grid to Improve Safety & Reliability



• Distribution; Demand-Side Management iii. Objective

• This project aims to validate and integrate a software platform to identify photovoltaic (PV) resources by leveraging Smart Meter™ data. This project focuses on addressing the issue of unauthorized interconnections in an automated fashion by developing and algorithm to identify resources, including integration with Pacific Gas and Electric Company (PG&E) billing and interconnection database, as well as develop an automated outreach system for identified customers.

• This project addresses California Public Utilities Commission proceeding, R.11-09-011 Rule 21 to support the improved distribution-level interconnection rules and regulations for certain classes of electric generators and electric storage resources.

iv. Scope

• Identify vendor to develop or pilot software.

• Develop integration and communication platform for auto-identification of Unauthorized Interconnections (UI).

• Demonstrate ability to automatically integrate software with billing and interconnection. v. Deliverables

• Successful integration of software with PG&E’s Customer Care and Billing (CC&B) system.

• Successful tracking of all UIs identified.

• Successful tracking of communication and “conversion” of UIs to interconnection. vi. Metrics


• 5f – Reduced flicker and other power quality differences.

• 5c – Forecast accuracy improvement. vii. Schedule



• $1,327,782

63

x. Partners (if applicable)





• Patent filed for an algorithm which can detect unauthorized PV Interconnections. xv. Status Update



64

Project #1.22 – Demonstrate Subtractive Billing With Submetering for EVs to Increase Customer Billing Flexibility




• EV submetering pilot to test subtractive metering process and Electric Vehicle Service Provider (EVSP) business models.

• This project addresses CPUC D.13-11-008, which requires PG&E, along with the other two California Investor-Owned Utilities (IOU), to pursue a submetering pilot and eventual protocol.

iv. Scope

• Electric Vehicle (EV) submetering pilot will entail EV Meter Data Management Agents (MDMA) delivering submeter data to IOU for subtraction from customer’s primary meter to create an EV and a house bill. Customer will be responsible for both bills. In Phase 2, an additional business model will be introduced where the MDMA will be responsible for the bill to PG&E.

v. Deliverables

• Process to receive MDMA submetered data.

• Process to subtract EV data from primary meter to create two bills.

• Inclusion of EV portion of bill on customer’s monthly bill.

• Process for billing MDMA for participant submeter charges.

• Obtain third-party evaluator for both phases of pilot through a Request for Proposal (RFP).

• Incentive payments to MDMA. vi. Metrics


• 1h – Customer bill savings (megawatt-hours saved). vii. Schedule

• 5 years viii. EPIC Funds Encumbered


• $1,924,128

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x. Partners (if applicable)






• Project is in the Build/Test phase.

• Phase 1 evaluation report released in 2016, project received CPUC approval for launch of Phase 2, adding an additional business model for the MDMA to hold contracts with customers be responsible for the EV bill to PG&E.

• Phase 2 commenced January 1, 2017 with 4 out of 6 approved MDMAs confirmed for participation and ended April 30, 2017, yielding 264 of the expected 500 customer enrollment goal.

• Completed data loggers installation on submeters in participant homes to provide accuracy data for overall evaluation.

• Presented participant welcome survey to CPUC with the following findings; PG&E achieved an 85% response rate on survey, 55% of Phase 1 participant indicated that the Phase 2 experience has been better, 45% of respondents reported switching to charging off-peak during the demonstration.

• Next steps include continuation of processing MDMA incentive payments, de-enroll participants and decommission submeters, draft and publish Final Report.

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Project #1.23 – Demonstrate Additive Billing With Submetering for PVs to Increase Customer Billing Flexibility



• Grid Ops and Market Design/Distribution/Demand-Side Management iii. Objective

• Initiative to obtain additional un-netted Photovoltaic (PV) data to support customer call center bill experience, and provide additional service to its customers. PV generation data will be integrated with existing MyEnergy web portal for customers’ benefit.

• This project addresses California Public Utilities Commission proceeding, Net Energy Metering R.12-11-005 and R.11-09-011 Rule 21.

iv. Scope

• Explore four different methods for obtaining PV generation data (Dedicated SmartMeter™, submeter communication via ZigBee radio, third-party estimates, and data exchange with solar companies, and work with vendor to relay data to customer.

v. Deliverables

• Implement pilot program for dedicated smart meters and third-party estimates.

• Explore opportunities for submetering technology and solar company data exchange.

• Modify existing Customer Data Warehouse (CDW)/MyEnergy interface to allow for additional data streams and visualization.

• Evaluate relative merits of various generation measurement/estimation approaches. vi. Metrics

• 5c – Forecast accuracy improvements.


vii. Schedule





• N/A

67

xii. Match Funding Split (if applicable)






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Project #1.24 – Demonstrate Demand-Side Management (DSM) for Transmission and Distribution (T&D) Cost Reduction



• Transmission; Distribution; Grid Operation/Market Design; Demand-Side Management iii. Objective

• Assess how to best utilize DSM resources to create a targeted customer- and location-specific approach to assist with distribution capacity constraints.

• This project addresses California Public Utilities Commission proceeding, Distribution Resources Planning R.14-08-013, through improving efficiencies between interconnection and integration.

iv. Scope

• Improve ability to estimate Heating, Ventilation and Air Conditioning (HVAC) Direct Load Control (DLC) load impacts at the distribution feeder level to aid in better understanding of the localized impact of HVAC DLC devices on meeting distribution feeder level reliability concerns.

v. Deliverables

• Deploy data logging devices on a scientific sample of existing SmartAC™ Cycling customers, to enable real time monitoring of device performance and load impacts at feeder-level.

• Develop infrastructure to make real-time data available on feeder-level load impacts of SmartAC™ cycling to distribution operations.

• Produce report describing a case study methodology of targeting and valuing customer side peak load reductions at the feeder level.

vi. Metrics


vii. Schedule





• N/A

69






• Final Report was posted to EPIC, CalMac and Plug Load Management Associated (PLMA) websites, and included in 2016 EPIC Annual Report.

70

Project #1.25 – Develop a Tool to Map the Preferred Locations for DC Fast Charging, Based on Traffic Patterns and PG&E's Distribution System, to Address EV Drivers' Needs While Reducing the Impact on PG&E's Distribution Grid




• Develop, pilot, and validate approaches that help determine the optimal location of DC fast chargers based on traffic patterns and distribution grid infrastructure.

iv. Scope

• Acquire travel pattern data and grid infrastructure capability data to identify low-cost, high utilization areas in which to integrate DC fast chargers into Pacific Gas and Electric Company’s (PG&E) distribution system.

v. Deliverables

• Develop a process to identify optimal DC fast charging sites.

• Develop a map that presents the locations of optimal DC fast charging sites in a meaningful manner to customers.

vi. Metrics

• 3a – Maintain/Reduce capital costs.

• 3d – Number of operations of various existing equipment types before and after adoption of a new smart grid component, as an indicator of possible equipment life extensions from reduced wear and tear.

• 4a – Greenhouse Gas emissions reductions (MMTCO2e).



• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid (Public Utilities Code § 8360).

• 7l – Identification and lowering of unreasonable or unnecessary barriers to adoption of smart grid technologies, practices, and services.

vii. Schedule




• N/A

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72

Project #1.26 – Pilot Measurement and Telemetry Strategies and Technologies That Enable the Cost-Effective Integration of Mass Market Demand Response (DR) Resources into the CAISO Wholesale Market



• Grid Operation/Market Design and Demand-side Management. iii. Objective

• Develop, demonstrate and validate approaches and technologies that enable the cost-effective integration (specifically, the measurement and telemetry) of mass market DR resources into the California Independent System Operator (CAISO) wholesale market. While other DR projects focus on integration of DR resources into various utility and future Independent System Operator operational needs, this project intends to test alternative telemetry solutions and technologies to satisfy CAISO operational visibility requirements.

iv. Scope











• TBD

73

xv. Status Update


74

Project #2.01 – Evaluate Storage on the Distribution Grid


• 2nd Triennial (2015-2017) ii. Assignment to Value Chain

• Grid Operations/Market Design; Transmission; Distribution; Demand-Side Management iii. Objective

• Identify and evaluate whether system needs can be cost-effectively addressed with energy storage, including identifying a range of storage deployment locations and grid interconnection requirements on a granular level.

iv. Scope

• TBD v. Deliverables

• TBD vi. Metrics


• TBD viii. EPIC Funds Encumbered









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Project #2.02 – Pilot Distributed Energy Resource Management Systems (DERMS)




Demonstrate new technology to monitor and control Distributed Energy Resources (DERs) to manage system constraints and evaluate the potential value of DER flexibility to the grid. The DERMS demonstration will drive learning about the people, process, and technology needed to operate the high DER penetration grid of 2025.

• Define boundaries and integrations with other PG&E and external systems such as Demand Response Management System (DRMS), Advanced Distribution Management System (ADMS) and CAISO market systems among others.

• Identify limitations of existing as-built models and field telemetry data

• Evaluate the performance of aggregated DERs providing distribution services

• Create, test, and iterate on future DERMS requirements (e.g., communication requirements for PG&E and third-party owned DERs).

• Learn about business process change and personnel skills & knowledge needed to implement DERMS.

• This project informs California Public Utilities Commission proceeding, Distribution Resources Plan R.14-08-013 to inform distribution planning by demonstrating DER integration into planning and operations.

iv. Scope

• Demonstrate minimum viable DERMS operation at Pacific Gas and Electric Company (PG&E) to address key DER management use cases.

• The demonstration will take place in a limited geography with a diverse set of DERs being monitored and controlled by the DERMS demonstration.

v. Deliverables

• The functional integration of a DERMS software minimum viable product and operational demonstration of the identified use cases.

• A report that: ▪ Determines the most important characteristics of a full deployment solution

including detailed functional and technical requirements. ▪ Identifies best practices and required internal capabilities for a full deployment

solution. ▪ Develops operational processes that can be scaled to a wider system

deployment. ▪ Defines boundaries and integrations with other PG&E systems (e.g., DRMS,

DMS, market systems).

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▪ Develops a point of view on the utility role in managing DERs for grid and economic benefits.

vi. Metrics


• 7d – Deployment and integration of cost-effective distributed resources and generation, including renewable resources (Pub. Util. Code § 8360).

vii. Schedule





• $419,000 xii. Match Funding Split (if applicable)





• Completed site acceptance testing and IT build. DERMS is currently live in the field

• Nine data interfaces developed and tested: weather and generation forecasters, DG aggregators, AMI and SCADA systems. Successfully completed the DERMS foundation allowing the commencement of use case testing.

• Began field demonstration of seven use cases in July

• Installed of Phasor Measurement Units (PMUs) at existing substation and near the BESS and assessed the impacts of market participating BESS on operating conditions.

• Next steps include completion of use case demonstration, M&V analysis, Final Report completion and project closeout

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Project #2.03A – Test Smart Inverter Enhanced Capabilities – Photovoltaics (PV)




• This project will explore the use and impact of aggregated customer-sited smart inverters to help inform emerging industry standards, as well as define the operational and communication requirements to support the advancement and deployment of new inverter technologies.

• This project addresses California Public Utilities Commission proceeding, Distribution Resources Plan R.14-08-013, by informing Distributed Energy Resources modeling by incorporating Smart Inverters. The findings of this report will also support and inform PG&E’s position within the Rule 21 open proceeding.

iv. Scope

• This project leverages the results of the lab testing of smart inverter functionalities that is being completed by PG&E’s Smart Grid Pilot Volt/Var Optimization (VVO) Project at G&E’s Applied Technologies Services (ATS) Lab (as specified by the Smart Inverter Working Group).

• This EPIC project will deploy smart inverters on one or more feeders to evaluate their effectiveness in improving PV integration, supporting and mitigating grid needs and safety risks.

v. Deliverables

• Identify feeder(s) where Smart Inverters will be installed for demonstration.

• Demonstrate the use of Smart Inverters on one or more feeders to demonstrate the inverters’ local voltage control capabilities and impacts related to high penetration of customer-sited solar PV.

• Develop necessary communications software/hardware/technologies between the utility and third-party aggregator or end devices.

• Evaluate the performance of Smart Inverters to support grid needs. vi. Metrics


• 7d – Deployment and integration of cost-effective distributed resources and generation, including renewable resources.

vii. Schedule


• $1,574,148

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• Successful completed Volt/Watt functionality and Volt/Var functionality acceptance testing in August and September respectively.

• Initial deployment of the technology showed the following:

• Customer acquisition and targeted deployment of DERs is challenging.

• Smart inverter technology is able to affect local premise voltage.

• Implementation of an aggregator solution unveiled that the uptime communications are not within traditional utility uptime requirements. However, the latency of the devices meets or exceeds that of PG&E’s SCADA system.

• The project is deploying Smart Inverter technology on a commercial feeder in 2018, with ~35% feeder penetration. Through this the project team expects to better understand recommendations around: smart inverter settings, effects of primary and secondary voltage, benefits of a third-party monitor and control platform and cost comparisons of smart inverter technology compared to traditional utility infrastructure upgrades.

• Next steps include completion of use case testing of smart inverter on a voltage constrained distribution feeder, M&V analysis, Final Report completion and project closeout

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Project #2.03B – Test Smart Inverter Enhanced Capabilities – Vehicle to Home




• Assessment of the use and impact of EV energy flow capabilities as a complement to the smart inverter assessment related to Photovoltaics (PV) in project 2.03A Smart Inverters for PV.

iv. Scope

• Technology demonstration for charging and discharging of the Electric Vehicle (EV) in response to demand response or hard islanding events.

• Testing multiple test modes.

• Technology assessment from customer and ratepayer perspectives through a customer survey and a cost-benefit evaluation.

v. Deliverables

• Evaluation of the performance of the EV energy flow capabilities to support residential load during DR and hard islanding events.

• Cost-benefit evaluation vi. Metrics



vii. Schedule







• Pay for Performance

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• The project demonstrated that a bi-directional EV and charger can support critical household loads through an outage. However, the project also determined that, in addition to the technology not being commercially available, it is not cost effective for customers to adopt. This was supported by the project’s customer survey results which indicate the current cost estimate is roughly 4 times higher than an optimal price for consumers. Therefore, even though the project use cases were technically proven—they are not currently feasible due to technology cost, limited market value, and other restrictions between actors (e.g. EV battery warranty coverage).


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Project #2.04 – DG Monitoring & Voltage Tracking



• Grid Operations/Market Design iii. Objective

• Utilization of the voltage measurement capabilities of SmartMeter™ devices to monitor Distributed Generation (DG) output and identify voltage fluctuations caused by the intermittent nature of distributed renewable resources.

• Use of data analytics techniques and Advanced Metering Infrastructure (AMI) (and other) data to determine the impact of PV penetration on Rule 2 violations and

• Create rating for the probability that a Rule 2 violation is caused by DG. iv. Scope

• Create an algorithmic process output rating on the likelihood of a voltage violation (on a given transformer) being caused by DG fluctuations.

v. Deliverables

• Develop an analytics process/algorithm to analyze AMI and other data for high penetration DG feeders, as well as some low penetration feeders for baselining.

• Evaluate impact of DG penetration on voltage. vi. Metrics




vii. Schedule






• TBD

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• This project demonstrated an algorithmic process for analyzing new data sources (including SmartMeter™ devices and databases of solar irradiance) to predict the likelihood that a Rule 2 voltage violation was caused by distributed solar generation. Solar energy is by nature intermittent, and ebbs and surges of generation can change the voltage for neighboring, downstream customers. This functionality, if integrated into a larger grid analytics platform, might improve decision making for power quality engineers responding to customer issues.

• Final Report included in this 2017 EPIC Annual Report.

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Project #2.05 – Inertia Response Emulation for DG Impact Improvement



• Grid Operations/Market Design; Transmission iii. Objective

• Demonstrate the capability to emulate inertia injection and support primary frequency control using energy storage and smart inverter technologies to potentially mitigate the impacts of large-scale Distributed Generation (DG) to the grid, improve the grid performance and reliability, and advance California energy policy to increase the amounts of renewable and distributed generation on the grid.

iv. Scope

• Develop computer models to evaluate inverter capabilities and demonstrate possible future system needs for new inertia support solutions.

• Analyze and optimize the present technology’s energy storage inertial response capabilities via Power-Hardware-In-Loop testing.

v. Deliverables

• Evaluation of the power system’s need for reliability support, including identifying threshold conditions.

• Assessment of the capabilities of present energy storage inverters for inertial frequency response functions.

• Provide recommendations for future inverter and interconnection requirements to provide inertial response.

vi. Metrics

• 1a. – Number and total nameplate capacity of distributed generation facilities

• 1b. – Total electricity deliveries from grid-connected distributed generation facilities

• 1i. – Nameplate capacity (MW) of grid-connected energy storage

• 3e. – Non-energy economic benefits (reliability)

• 5a. – Outage number, frequency and duration reductions

• 7b. – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid (PU Code § 8360)

• 7d. – Deployment and integration of cost-effective distributed resources and generation, including renewable resources (PU Code § 8360)

• 7h. – Deployment and integration of cost-effective advanced electricity storage and peak-shaving technologies, including plug-in electric and hybrid electric vehicles, and thermal-storage air-conditioning (PU Code § 8360)

vii. Schedule

• 2 years

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viii. EPIC Funds Encumbered



• National Renewable Energy Laboratory selected as testing and demonstration provider. xi. Match Funding (if applicable)





• Project is in the Design/Engineering phase.

• NREL engaged as demonstration site.

• Next steps Include, test bed & energy storage commissioning, synthetic inertia use case testing of energy storage, and modeling and simulation to evaluate system-scale capabilities and validate application scenarios

85

Project #2.06 – Intelligent Universal Transformer (IUT)



• Distribution; Grid Operation/Market Design; Demand-Side Management” iii. Objective

• Develop and demonstrate a solid-state transformer field prototype Medium Voltage Fast Charger (MVFC) system, as an application use case of solid-state transformers for Direct Current (Direct Current) fast charging of Plug-In Electric Vehicles (PEV), featuring intelligent controls and multiple fast charging of PEVs.

iv. Scope

• Test demonstration and communication to the same DC solid-state transformer with two protocols.

v. Deliverables

• Develop a proof of concept that may demonstrate: 1. An Intelligent Universal Transformer (IUT) can be used in lieu of other equipment

to connect to Direct Current Fast Charge (DCFC) protocols, and 2. An IUT can communicate back to the utility.

vi. Metrics




• 7k – Develop standards for communication and interoperability of appliances and equipment connected to the electric grid, including the infrastructure serving the grid.

• 7l – Identification and lowering of unreasonable or unnecessary barriers to adoption of smart grid technologies, practices, and services.

vii. Schedule






• N/A

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• Project put on hold after determining the product (IUT) was not mature enough for a technology demonstration through EPIC.

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Project #2.07 – Real-Time Loading Data for Distribution Operations and Planning



• Grid Operation/Market Design; Distribution iii. Objective

• This demonstration will leverage interval data to improve feeder modeling, inform near real time load allocation throughout the distribution grid and transformer loading profiles, and identify opportunities to enhance current load forecasting processes for distribution transformers, feeders and substation transformers.

iv. Scope

• Utilize AMI and other data sources to develop an algorithm to improve the prediction of grid loading.

• Demonstrate the aggregation of this loading up through the distribution model to enhance distribution planning as well as real time distribution grid operations.

v. Deliverables

• Develop a unique loading algorithm and rubrics for determining cost-effective data sources and cadences.

vi. Metrics

• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid.

vii. Schedule








• N/A

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xv. 2017 Status Update


• Gathered stakeholder input on preliminary prototype application developed by vendor.

• Transitioned vendor model into PG&E environment, integrated model with real-time data inputs, and continued to refine the model.

• Next steps include addressing remaining issues with model input data, further refining and validating the model, and deriving requirements for future ADMS.

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Project #2.08 – “Smart” Monitoring and Analysis Tools




• Demonstrate strategies and technologies for real time, online monitoring of substation equipment; Demonstrate communication protocols and equipment to support the smart devices; Develop visualization techniques for improved monitoring; and evaluate new vendor technologies that enable data correlation and predictive analysis to better identify and respond to potential safety, reliability and/or operational issues.

iv. Scope


• TBD vi. Metrics











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Project #2.09 – Distributed Series Impedance (DSI) Phase 2




• Demonstrate congestion mitigation by installing DSIs on parallel transmission facilities to demonstrate the next generation of the Distributed Series Reactor (DSR) devices from the First EPIC Triennial Plan, which may allow for better control of transmission line loading.

iv. Scope


• TBD vi. Metrics











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Project #2.10 – Emergency Preparedness Modeling




• Incorporate natural hazard damage model information into one integrated algorithm/tool, which would provide the ability to quickly estimate the impacts of natural hazards on Pacific Gas and Electric Company facilities to enable faster response and restoration.

• Provide the ability to prepare for these hazards by proactively modeling the impacts of potential hazards, to understand system vulnerabilities and restoration resource requirements.

• Incorporate work optimization algorithms to more efficiently allocate crews.

• Utilize artificial intelligence and statistical methods to model productive rates and automatically develop restoration plans.

iv. Scope

• Develop optimization algorithms and visualization tool that includes asset locations and conditions with multiple potential hazards, which allows for the aggregation of equipment damage estimates (via damage models, outage information systems, and damage assessments), est. hours to repair, and recommended allocation of work resources to efficiently respond to a natural hazard.

v. Deliverables

• Complete algorithms that aggregate data from multiple sources to feed into application.

• Incorporate multiple algorithms into a proof of concept visualization tool.

• Develop recommendation for deployment strategy. vi. Metrics


• 4a – Greenhouse Gas emissions reductions (MMTCO2e).




• 5c – Forecast accuracy improvement. vii. Schedule


• $2,425,012

92







• PG&E will receive perpetual, transferable sublicenses to all Work Product to use for current and future PG&E business.



• Developed initial prototype of optimization model and associated visualization tool.

• Established live data interfaces to the prototype and demonstrated the model’s ability to recommend the optimized allocation of work resources to respond to emergency events.

• Next steps include migration of the prototype to a self-contained cloud solution, connecting the cloud solution to a real-time data repository, enhancing the user interface and its alignment with predefined use cases and Emergency Operations Center processes, and conducting demonstration assessment of the tool during events this upcoming storm season.

93

Project #2.11 – New Mobile Technology & Visualization Applications




• Demonstrate tailored, advanced mobile applications for Pacific Gas and Electric Company field operations that build upon Grid Operations Situational Intelligence (Project #15) demonstration projects in the EPIC First Triennial Plan as well as existing “baseline” mobile deployments underway.

iv. Scope


• TBD vi. Metrics











94

Project #2.12 – New Emergency Management Mobile Applications




• Develop new mobile applications to enhance Pacific Gas and Electric Company’s emergency preparedness and response capabilities.

iv. Scope


• TBD vi. Metrics











95

Project #2.13 – Digital Substation/Substation Automation




• Investigate and evaluate sustainable protection and control technologies for future “digital” substations, which may include testing technologies in a lab setting, and performing a pilot implementation to demonstrate technology adoption and integration with legacy substation protection and control technologies.

iv. Scope


• TBD vi. Metrics











96

Project #2.14 – Automatically Map Phasing Information




• This project aims to explore a variety of pre-commercial analytics and/or hardware options to automatically map 3-phase electrical power information in order to improve the distribution network models.

iv. Scope

• Project seeks to improve distribution network models through automatic mapping of 3-phase electrical power information.

v. Deliverables

• Develop algorithm or novel process to use AMI data and other sources to determine the assignment of Phases to conducting components.

• Complete an analysis on the most cost-effective frequency for running such a mapping process.

vi. Metrics


vii. Schedule




• PG&E is working with University of California, Riverside to test an alternate algorithm based approach which will be evaluated against other solutions demonstrated in project





• N/A

97



• Brought on 4 vendors that each developed phase identification algorithms and meter to transformer algorithms, developed testing processes and began assessing the performance of each vendor’s algorithms.

• Collected additional data from 4 feeders and used to further refine and validate algorithms.

• Next steps include finalizing algorithms and developing a validation model to compare the final results of these various algorithms

98

Project #2.15 – Synchrophasor Applications for Generator Dynamic Model Validation




• This project will demonstrate new synchrophasor analysis applications that can perform generator dynamic model parameter estimation and validation using disturbance data recorded by the synchrophasor system. New synchrophasor applications could perform mandated generator model validation without requiring time- and labor-intensive on-site tests, and could detect sub-synchronous resonance and other conditions which can cause generator outages.

iv. Scope

• Scope is limited to confirming that analysis of Phasor Measurement Unit (PMU) data is better than costly on-site model validation in the target geography. Scope does not include widespread deployment of PMUs.

v. Deliverables

• Install synchrophasors (or “PMUs”) on generators or generator tie-lines, and demonstrate new data analysis software applications.

• Evaluate the applications’ ability to perform generator dynamic model validation by analyzing synchrophasor data following transient disturbances on the transmission system.

vi. Metrics




vii. Schedule





• TBD

99





• Project is in the Closeout phase.

• Installed a fully functional stand-alone PMU system at Colusa Power Generating Station during a scheduled generator outage;

• Developed generator station models and

• For the disturbances captured by the PMUs, the existing models were improved and validated without requiring a generator shutdown.

• Next Steps include completion of final report.

100

Project #2.16 – Enhanced Synchrophasor Analytics & Applications




• Demonstrate new techniques to synthesize Synchrophasor data and utilize the data for advanced real-time system applications, such as wide-area monitoring, protection, and control systems, which could help move Synchrophasor applications beyond planning, forensics, and visualization to enhanced wide-area monitoring, protection, and control applications.

iv. Scope


• TBD vi. Metrics











101

Project #2.17 – Geomagnetic Disturbance (GMD) Evaluation




• Evaluate system vulnerability to GMD by modeling GMD that occurs during a geomagnetic storm and evaluating the impact on transmission lines, interconnection lines, substations and system voltages.

iv. Scope


• TBD vi. Metrics











102

Project #2.18 – Optical Instrument Transformers and Sensors for Protection and Control Systems




• Demonstrate newer technologies, such as optical sensors, as well as strategies and technologies to configure appropriate protection settings, including the coordination required between both new and conventional instrumentation.

iv. Scope


• TBD vi. Metrics











103

Project #2.19 – Enable Distributed Demand-Side Strategies & Technologies




• Demonstrate distributed energy storage and approaches to address local and flexible resource needs.

• This project addresses California Public Utilities Commission proceeding, Distribution Resources Plan R.14-08-013, by demonstrating DER locational benefits and addressing capacity constraints through aggregated behind-the-meter (BTM) customer energy storage.

iv. Scope

• Deploy an aggregation of BTM customer energy storage resources to reduce peak loading or absorb distributed generation on a utility distribution feeder(s).

v. Deliverables

• Demonstrate and test field results for effectiveness of the use of aggregated customer-sited BTM energy storage resources to peak load reduction and/or absorb distributed generation on a utility distribution feeder(s).

• Demonstrate communications with aggregated resources for visualization and control.

• Evaluate cost-effectiveness and reliability of BTM energy storage for addressing capacity constraints.

vi. Metrics


• 1i – Nameplate Capacity of Grid-Connected Storage.

• 3f – Improvements in system operation efficiencies stemming from increased utility dispatchability of customer demand side management.

• 5b – Electric system power flow congestion reduction.




vii. Schedule


• $1,678,045

104







• N/A – No current evidence of Intellectual Property development xv. 2017 Status Update


• Demonstration installation complete, field demonstration acceptance testing complete

• Use Case testing complete

• Project Key Findings: ▪ Current vendor platforms for controlling customer-sited DERs are not ready for

utility operations ▪ Communications to devices are not comparable to traditional utility

communications ▪ Latency is comparable to current utility SCADA ▪ Aggregated customer storage is effective for premise load drop. ▪ Implementation of command prioritization would be required for future multiple-

use applications.


105

Project #2.20 – Real-Time Energy Usage Feedback to Customers



• Grid Operations/Market Design; Distribution; Demand-Side Management iii. Objective

• Evaluate innovative feedback technologies to provide near real-time energy usage information to customers and to drive greater customer performance during DR events.

iv. Scope


• TBD vi. Metrics











106

Project #2.21 – Home Area Network (HAN) for Commercial Customers




• This project will demonstrate the application of HAN technology to Pacific Gas and Electric Company’s commercial customers.

iv. Scope

• This project will enable the Zigbee HAN radio on Large Commercial and Industrial (LCI) meters, to facilitate LCI customer access to real time usage data, as well as testing of the integration with existing Energy Management Systems (EMS).

v. Deliverables

• Install Zigbee HAN devices with selected LCI customers and connect devices to their SmartMeter™.

• Monitor customer usage and issue/collect customer surveys.

• Complete report with identified issues and recommendations for how to integrate with an existing EMS.

vi. Metrics

• 1e – Peak load reduction (megawatts) from summer and winter programs.

• 1f – Avoided customer energy use (kilowatt-hours saved).


• 3a – Maintain / Reduce operations and maintenance costs.


• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid (Public Utilities Code § 8360).

vii. Schedule




• Rainforest Automation providing development of the cloud service application used by the customers


• TBD

107




• N/A – No current evidence of Intellectual Property development xv. 2017 Status Update


• Completed execution of field testing, field surveys, and data to compile results and findings.

• Identified adoption, integration, and utilization barriers associated with mass deployment of real time Zigbee data through HAN devices.

• Final Report included in 2017 EPIC Annual Report

108

Project #2.22 – Demand Reduction Through Targeted Data Analytics




• Identify strategic customers and target demand reduction in local areas by combining and integrating multiple Demand-Side Management technologies (e.g., Energy Efficiency (EE), Demand Response (DR), Distributed Energy Storage, and Consumer-oriented Energy Tools).

• Investigate whether Pacific Gas and Electric Company can achieve a sufficient amount of demand reduction through visibility into the customer-side resources, and improve the reliability of customer-side resources at the local level in order to reschedule local capacity expansion expenditures.

• This project addresses California Public Utilities Commission proceeding, Distribution Resources Plan R.14-08-013, by supporting the fair and transparent processes for Distributed Energy Resource (DER) deployment and integration.

iv. Scope

• Develop a solution/tool that determines needed customer demand reduction individually and in aggregate at asset level, leveraging interval and Supervisory Control and Data Acquisition (SCADA) data.

• Develop cross-DER customer targeting to address forecasted capacity challenges at specific assets, for specific days and times of year, leveraging interval data and other customer attributes.

v. Deliverables

• Create a data analytics platform capable of combining and analyzing multi-structured data, linking to a variety of data sources.

• Develop a method for identification, valuation, implementation, and tracking of targeted DERs.

• Create a quantitative screening/rank order tool.

• Develop actionable DER recommendations to customer outreach teams for reaching demand reduction goals.

vi. Metrics

• 3a – Maintain/Reduce capital costs.


• 7e – Development and incorporation of cost-effective demand response, demand-side resource, and energy efficient resources.

• 7h – Deployment and integration of cost-effective advanced electricity storage and peak-shaving technologies.

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vii. Schedule










• Integrated Energy Efficiency (EE) Load Shapes into model

• Completed work on Customer Propensity model

• Incorporated E3 energy storage model and tested and validated DR model

• Finalized all DER load shapes, dispatch, customer selection criteria

• Completed front end development with work on optimization function

• Next steps include optimization improvement, Traditional Wires Alternatives to be added to tool optimization, Final Report completion and project closeout.

110

Project #2.23 – Integrate Demand Side Approaches Into Utility Planning




• This project will enhance Pacific Gas and Electric Company’s ability to incorporate the growing usage of Distributed Energy Resources (DER) into distribution planning tools by developing new customer class load shapes that incorporate DERs, and a methodology for modeling DER deployment uncertainty at the circuit level.

• The execution of this project addresses issues as identified in the following proceedings: Distribution Resources Plan R.14-08-013 and Assembly Bill 327 Section 769, which requires transparent and consistent methods to integrate cost-effective DERs into the distribution planning process.

iv. Scope

• Integrate a broader range of customer-side technologies and DER approaches into grid planning and operations in a least cost framework by enhancing distribution load forecasting tools to include new customer load shapes based on the usage of DERs and to model the uncertainty of DER deployment at the circuit level.

v. Deliverables

• Develop enhanced Customer and DER Load Shapes Catalog in PG&E’s LoadSEER Planning Tool.

• Incorporate DER Scenario Projections into LoadSEER.

• Develop interface between LoadSEER and CYME for batch processing integration. vi. Metrics




• 7e – Development and incorporation of cost-effective demand response, demand-side resources, and energy-efficient resources (Public Utilities Code § 8360).

vii. Schedule




• TBD

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• This project successfully developed and demonstrated the integration of a broader range of customer-side technologies and Distributed Energy Resources (DER) approaches into the utility planning process.

• The project served as a necessary and enabling precursor to the fulfillment of Public Utility Code 769, which requires transparent, consistent and more accurate methods to cost-effectively integrate DERs into the distribution planning process.

• This project delivered new load shape profiles, enhanced load forecasting tool and overall analytical process that allows PG&E to more accurately and consistently integrate DER impact to the distribution system load profile.

• With these enhancements, PG&E can more effectively assess the impact of DER growth on the timing and need for future distribution and transmission system upgrades.

• Final Report included in this 2017 EPIC Annual Report.

112

Project #2.24 – Appliance Level Bill Disaggregation for Non-Residential Customers




• Demonstrate the ability to use sub-minute level usage information to determine appliance load for non-residential customers.

iv. Scope


• TBD vi. Metrics











113

Project #2.25 – Enhanced Smart Grid Communications




• Evaluate license spectrum providers that have developed technologies offered on the Federal Communications Commission (FCC) license frequency range/spectrum.

iv. Scope


• TBD vi. Metrics











114

Project #2.26 – Customer & Distribution Automation Open Architecture Devices




• Demonstrate the means by which new customer and distribution devices could interoperate with Pacific Gas and Electric Company’s Advanced Metering Infrastructure (AMI) network (IPv6).

iv. Scope

• Demonstrate the methodology, protocols, and standards for customers and vendors to connect and communicate various new devices and applications (e.g., Home Area Network, Electric Vehicle charging, smart appliances, etc.) with the AMI network (IPv6) in an effective manner.

v. Deliverables

• Conduct testing that will certify customer open architecture devices/applications that are AMI compatible, secure and interoperable.

• Provide physical and application interfaces, as a proof of concept, which may permit customer and third-party devices to connect to PG&E’s AMI network(s).

vi. Metrics


• 5i – Increase in the number of nodes in the power system at monitoring points.

• 7j – Provide consumers with timely information and control options. vii. Schedule







• TBD

115



• Project in Design/Build phase

• Established use-cases for AMI technology demonstration including – ▪ The ability to communicate, control, transmit data, and upgrade firmware onto

FLISR overhead and underground devices over the network ▪ Direct acquisition and control telemetry solution with enhanced security and

cyber isolation for medium-sized energy generation projects. ▪ The ability to communicate with RFID equipment over the network.

• Next Steps include execution of use-cases in lab and/or field environments.

116

Project #2.27 – Next Generation Integrated Smart Grid Network Management i. Investment Plan Period



• Evaluate new technologies to holistically monitor, control and evolve the communications network and supporting infrastructure as a platform to enable Smart Grid solutions.

iv. Scope

• Demonstrate a new Advanced Metering Infrastructure (AMI) Network management system to holistically monitor, control, and evolve the existing AMI network and infrastructure from a billing-centric platform to a fully operational AMI solutions platform that will meet evolving customer and grid needs.

v. Deliverables

• Demonstrate an integrated, multi-tenant network management system that may include the following features:

▪ Integrated network management & control that will monitor and prioritize data traffic.

▪ Automate trouble ticketing creation process for workflow management. ▪ Asset management of meter and network equipment regardless of meter or

network types. vi. Metrics









• TBD

117





• Project is in the Closeout phase.

• Developed a demonstration grade management platform that successfully identified inventory, configuration, and performance data for all three AMI networks including both networking elements and metering endpoints.

• The project learned the complexity of adding functions needed such as additional Head-End Network Management functions, integration with GIS layers (i.e., data sources like CC&B, MDMS), and integration with various PG&E ticketing systems (Remedy, FAS). Based on this complexity, an enterprise management system will be needed to scale the functions demonstrated through this project.

• Next Steps include completion of close-out report.

118

Project #2.28 – Smart Grid Communications Path Monitoring




• Evaluate communication paths for AMI related messages, including methods to clear potential interference, congestion, validate proper authorizations, and grant clearances for sending message over a secured communication path.

iv. Scope

• Determine the ability to identify, analyze, and diagnose Radio Frequency (RF) interference that can occur along the communication path from the meter through the data collectors to the AMI vendors’ control system.

v. Deliverables

• Establish the baseline noise floor.

• Develop and demonstrate an application with an algorithm which can automatically and continuously identify, monitor, and confirm RF interferences for multiple spectrums.

• Provide an end-end process for identifying, confirming and mitigating detected interferences with the AMI-network.

vi. Metrics


• 3e – Non-energy economic benefits – reduction operational hours to fix estimated bills due to RF Interference.

vii. Schedule







• TBD

119




• Developed a network configuration plan that would enable PG&E to gather relevant external data sources through a secure VPN tunnel onto PG&E’s network.

• Identified minimum data points and sources of this data to pursue the technology demonstration.

• This project has been sunset early based on findings that the data required for the algorithm to be effective was not available (neither via internal nor external sources).

• Final Report included in 2017 EPIC Annual Report

120

Project #2.29 – Mobile Meter Applications




• Demonstrate the utility’s ability to enable dynamic electric mobile metering. iv. Scope

• Develop and test a mobile meter prototype on various applications that can be used to capture and monitor real-time energy transactions and usage (e.g. Plug-In Electric Vehicles (PEV), Distributed Generation (DG), mobile storage, etc.).

v. Deliverables

• Design specification of mobile meter.

• Demonstration of mobile meter hardware prototype.

• End-to-end meter to cash testing using existing AMI or cellular based network.

• Demonstration of use-cases on DG applications and PEV metering, including remote and near real-time tracking of vehicle charge locations and energy flow.

vi. Metrics

• 3a – Maintain/Reduce operations and maintenance costs (Affordability).

• 7b – Increased use of cost-effective digital information and control technology to improve reliability, security, and efficiency of the electric grid (Reliability).

• 7j – Provide consumers with timely information and control options (Customer). vii. Schedule




• Lawrence Livermore National Lab providing technical support for product development xi. Match Funding (if applicable)




121


• Provisional patent filed for the multi-purpose mobile meter (Next Generation Meter - NGM).



• Finalized acceptance testing procedure for Next Gen Meters (NGM) • Conducted functional and acceptance testing on alpha and beta NGM prototypes. • Demonstrated mobile application of NGM prototype at PG&E • Next Steps include refining integration of accelerometer into the NGM, designing,

implementing and testing ANSI Standards C12.19 and C12.22 and head end application into NGM, and integrating 900 MHz network card technology into the NGM to leverage the existing AMI network for communication

122

Project #2.30 – Leverage EPIC Funds to Participate in Industry-Wide RD&D Programs



• Grid Operations/Market Design; Transmission; Distribution; Demand-Side Management iii. Objective

• Leverage EPIC dollars by participating and collaborating in multi-utility, industry-wide research, demonstration and deployment initiatives conducted by third-party organizations.

iv. Scope


• TBD vi. Metrics











123

Project #2.31 – Aggregated Behind-The-Meter Storage Market / Retail Optimization



• Grid Operations/Market Design; Demand-Side Management iii. Objective

• Demonstrate how aggregated behind-the-meter energy storage systems that are operated by a third-party dispatcher may address wholesale market needs, while also operating as a customer resource to reduce customers’ retail electric bills.

iv. Scope


• N/A vi. Metrics










• Formally Withdrawn by PG&E on 07/31/2017 via PG&E Comments on Draft Resolution E-4863

124

Project #2.32 – Electric Load Management for Ridesharing Electrification




• Evaluate grid impacts from Electric Vehicle (EV) charging used for ridesharing applications, to assess the ability to manage the resulting load using active demand management.

iv. Scope


• N/A vi. Metrics










• Deferred to a future investment plan by CPUC. Resolution E-4863. 08/10/2017

125

Project #2.33 – Service Issue Identification Leveraging Momentary Outage Information



• Grid Operations/Market Design; Distribution iii. Objective

• Leverage multiple sources of data, including but not limited to SmartMeter™, time of day, location and weather data, to proactively identify potential problems in the Electric Transmission and Distribution (T&D) system, specifically related to identifying locations with high incidences of momentary outages which may be caused by imminent failures of conductors, insulators, transformers and/or vegetation contact.

iv. Scope


• N/A vi. Metrics










• Deferred to a future investment plan by CPUC. Resolution E-4863. 08/10/2017

126

Project #2.34 – Predictive Risk Identification with Radio Frequency (RF) Added to Line Sensors



• Grid Operations/Market Design; Distribution iii. Objective

• Integrate additional sensing technology into communicating “smart” line sensors and demonstrate the ability to use that Line Sensor platform to monitor the grid and possibly predict potential outages.

iv. Scope

• Assess technical feasibility and potential sensor range to validate opportunity for business benefits.

• Integrate line sensor with additional sensing capability and set up physical test environment at ATS

• Develop test plan and conduct testing at ATS v. Deliverables

• Solution architecture for integrating additional sensor technology into line sensors. vi. Metrics

• 3a – Maintain / Reduce operations and maintenance costs

• 5a – Outage number, frequency and duration reductions

• 5d – Public safety improvement and hazard exposure reduction vii. Schedule

• 1 year viii. EPIC Funds Encumbered






• N/A

127


• TBD xv. 2017 Status Update

• Project is in the Plan/Analyze phase.

• Conducted preliminary assessment of industry capabilities

• Next steps include assessing technical feasibility and potential sensor range to validate opportunity for business benefits, developing and testing combined sensor solution, project closeout and project final report.

128

Project #2.35 – Call Center Staffing Optimization



• Grid Operations/Market Design iii. Objective

• Optimize call center staffing by developing a real-time algorithm that integrates with and improves upon existing call center staffing software to potentially predict variability in call volume impacts in near real-time.

iv. Scope


• N/A vi. Metrics










• Rejected by CPUC. Resolution E-4863. 08/10/2017

129

Project #2.36 – Dynamic Rate Design Tool



• Grid Operations/Market Design; Demand-Side Management iii. Objective

• Develop a new rate design tool that will enable complex rate design such as for DER adoption, with a more robust, quicker and powerful rate design approach than the current rate design process. Leveraging big data technologies, the tool will provide rapid optimization, analysis and evaluation of hypothetical new rate structures which will enable PG&E and parties in a rate case to make rate design decisions based on full information and nuanced sensitivity analysis.

iv. Scope

• Design and build cost of service database

• Design and build rate design model engine and API

• Build functionality and ability to run DER scenarios v. Deliverables

• Technical architecture specifications

• Data model and databases

• Rate design model engine and API vi. Metrics

• Time to complete the process of designing, optimizing, and analyzing the impact of a hypothetical rate design

vii. Schedule








130


• TBD xv. 2017 Status Update

• Project is in the Plan/Analyze phase

• Next steps include creating technical architecture specifications, develop data bases, develop test plan, build database and platform engine, develop and build API, final verification testing, project closeout and project final report.

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5. Conclusion

a. Key Results for the Year for PG&E EPIC Programs

Through the course of 2017, PG&E’s EPIC 1 and 2 Programs made significant progress and achieved noteworthy successes on many of the projects. Of the thirty-six projects started across EPIC 1 and EPIC 2, a total of twenty-two EPIC projects have completed (seven of these twenty-two projects completed in 2017 and/or before filing the 2017 EPIC Annual Report). PG&E is leveraging the learnings across projects and applying results into practice where applicable, including but not limited to:

• Leveraging technology developed in EPIC 1.01 – Energy Storage End Uses for future energy storage deployment. This includes the CAISO Automated Dispatch System developed through the project - an automated communications and control software for utility-scale BESS to participate in CAISO wholesale market. This project has informed new battery storage procurements and the project’s learnings are being used to enable more efficient and cost-effective integration of future battery storage resources into utility and market operations as PG&E strives to reach energy storage procurement targets.

• Leveraging the solar irradiance database that was developed and demonstrated in EPIC 1.05 – Demonstrate New Resource Forecast Methods to Better Predict Variable Resource Output to better predict variable resource output for advanced grid control programs in other PG&E projects. This database improves the ability to assess current and future grid impacts from PV generation to inform operational decisions with regard to planning and energy procurement.

• Leveraging some of the technologies developed in EPIC 1.19 – Pilot Enhanced Data Techniques and Capabilities via the SmartMeter™ Platform for operations, specifically the algorithm to detect line side tap conditions for revenue assurance, antennas/radios for remote metering communications, and processes for meter conversions to American National Standards Institute (ANSI) C12.19 standard format for more granular voltage and power quality data that was previously only available through on-site troubleshooting field visits. The project has shown the potential to, enable a proactive response to address customer satisfaction concerns on voltage issues, reduce manual meter reading operation and maintenance costs and improve the efficiency and effectiveness of investigating energy diversion cases and to mitigate safety hazards for customers, the public or PG&E.

• Leveraging the enhanced tool for incorporating DER scenarios into PG&E’s Distribution Planning load forecasts developed in EPIC 2.23 – Integrate Demand Side Approaches into Utility Planning. This includes the load shape catalog which is capable of archiving more than 5 million load shapes. PG&E used SmartMeter™ 2012-2014 interval data for all 5 million PG&E electric customers to create over 320,000 new load shapes (comprised of different aspects such as customer class, DER, feeder, bank and Distribution Planning Area (DPA)). Previously the load shapes catalog contained approximately 1,000 shapes (4 customer class load shapes for each DPA). The new load shapes include feeder load shapes, customer class load shapes, as well as DER adjustments for EV charging, PV production, EE load reduction, and DR program responses. The more accurate and granular load shapes allowed distribution planners to more precisely capture DER impact

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on the load growth forecast. As a result, PG&E was able to model DER deployment uncertainty at the circuit level in the context of the distribution planning process in a more standardized and transparent way. Any deferral of future distribution or transmission system upgrades would lower costs for electric ratepayers.

In addition to some of the post EPIC project level achievements listed above, since the inception of the EPIC Program, PG&E has established and maintained strong program management practices to provide oversight of the EPIC Program and ensure the maximum value of the projects to its customer base. In addition to oversight, the Program Management Office provides:

• Communications with interested vendors and suppliers through channels, such as referrals and industry events (e.g., Grid Edge Executive Council, Silicon Valley Leadership Group, DistribuTECH, etc.);

• Coordination with the other IOUs and CEC through regularly scheduled administrator meetings and collaboration;

• Collaboration with research entities, such as the Electric Power Research Institute (EPRI);

• Administrator-coordinated execution of industry-wide EPIC workshops and symposiums;

• Other EPIC Program support, such as providing comments and/or Letters of Support to select CEC Grant Funding Opportunities (GFOs).

PG&E’s EPIC portfolio of active projects continues to address challenges of the changing grid landscape, including enabling an increase in DER adoption by customers, the need to modernize the grid to ensure continued safe and reliable operation, and the need to continue improving affordability such as through advancing how to leverage data. These achievements from the EPIC projects, and their future path forward for those technologies that are proven ready to scale, help pave the way for the grid of the future, addressing upcoming challenges of a changing grid landscape and, ultimately, improving the safety, reliability and affordability of the electric grid.

b. Next Steps for EPIC Investment Plan

PG&E, in conjunction with the other EPIC Administrators, will continue to host stakeholder workshops and symposiums in 2018. These industry events will continue to focus on the sharing of progress, results, and future plans, improving coordination and understanding among the various stakeholders in the EPIC Program while raising awareness and visibility of EPIC investments and promoting program transparency. PG&E will also continue to promote the EPIC Program through participation in both internal and external public forums and other industry events.

PG&E and the other IOUs are currently waiting for CPUC decision and approval of the third triennial investment plan period of 2018-2020 (EPIC 3). Pending the timing of that decision, PG&E is excited to embark on the new technology demonstrations contained within that filing that can help meet emerging grid needs and California policy objectives. PG&E urges that the CPUC approve this plan promptly so as to not lose continuity with past plans and ensure that

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the customers and the state can leverage the maximum benefit of this program and the projects within.

c. Issues That May Have Major Impact on Progress in Projects

Inherent to the RD&D nature of the EPIC Program, market dynamics can change rapidly. Some potential reasons that can impact the projects’ progress include:

• Changes in the marketplace that may have made the project obsolete (or relatively less important to pursue)

• Different technologies have emerged that could produce better insights for the industry and PG&E customers, making some of the original proposed projects no longer the best use of available program funds

• The technology may prove to not yet be ready for commercialization and/or not yet ready nor capable to support the later stages of the original project objective

• The vendor interest may drop due to the small-scale demonstration size of the project or the vendor may revise their business model such that it is no longer aligned with the projects’ objectives.

Although these dynamics may impact a project’s progress, it is important to keep in mind that part of the value of RD&D is in both proving what is and what is not ready to scale. While the more obvious goal of technology demonstration is to help advance pre-commercial technologies, there are cases where success may be defined as determining that a project should not proceed to full scale until additional development takes place. This, both avoids more costly full production deployment before a technology is ready, and provides insight for the industry on what may need to be further developed.

PG&E mitigates some of the risk of this rapidly evolving technology landscape by managing the EPIC projects proactively. PG&E continually coordinates both internally and externally to stay aware of the latest technology demonstration needs, and practices enablement-focused governance over the project portfolio to help ensure successful and cost-effective technology demonstrations that emphasize continuous learning.


APPENDIX A

PROJECT STATUS REPORT

(SEE ATTACHED SPREADSHEET)

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

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17 A

NN

UA

L R

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RT

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th

e Project ‐ Objectiv

eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐ En

ergy Storage End

Uses

Rene

wab

les/DE

R Re

source

Integration

• De

velop techno

logies and

strategies fo

r efficien

t and

optim

ized bidd

ing an

d sche

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Energy Storage Techn

ologies (EST) in Califo

rnia In

depe

nden

t System Ope

rator (CA

ISO) m

arkets

and de

mon

strate th

ose strategies usin

g PG

&E’s e

xisting Sodium

Sulfur B

attery Ene

rgy Storage

System

s (NaS BESS).

• Th

is project a

ddresses th

e following CP

UC proceedings:

‐ As app

licab

le, o

peratio

nal experiences gaine

d from

this project can inform

outstan

ding policy

and im

plem

entatio

n iss

ues a

s ide

ntified

in Ene

rgy Storage Order In

stitu

ting Ru

lemaking 15

03

011.

• De

velop an

d de

ploy te

chno

logy to

ena

ble au

tomated

resource re

spon

se to

CAISO m

arket a

wards.

• Qua

ntify th

e values th

at battery re

sources c

an cap

ture in CAISO

markets.

• Establish

fina

ncial perform

ance of b

attery re

source participation in CAISO

markets.

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Re

source

Integration

• De

mon

strate th

e ab

ility of a utility

ope

rated en

ergy storage asset to ad

dress c

apacity

overload

s on the distrib

ution system

and

improve reliability.

• Th

is project a

ddresses th

e following Ca

lifornia Pu

blic Utilities Com

miss

ion (CPU

C)

proceedings:

‐ This p

roject will cou

nt to

wards th

e Investor Owne

d Utility

ene

rgy procurem

ent targets as s

et

forth in D.10 03

040

, the

Ene

rgy Storage Procurem

ent F

ramew

ork.

‐ As a

pplicab

le, o

peratio

nal experiences gaine

d from

this project can inform

outstan

ding policy

and im

plem

entatio

n iss

ues a

s ide

ntified

in Ene

rgy Storage OIR R.15 03

011

.

• De

ploy utility

ope

rated en

ergy storage asset a

t a single site.

• De

mon

strate peak shaving use case along with

other site‐spe

cific use cases as

suggested by distrib

ution op

erators.

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Re

source

Integration

• Th

e project a

ims to redu

ce existing ba

rriers to

dep

loym

ent o

f battery ene

rgy storage system

s by dem

onstratin

g whe

ther post‐electric veh

icle (E

V) “second

life” ba

tteries c

an cost‐effectively

perform electric distrib

ution services. Th

e project w

ill dem

onstrate th

e po

tential for re

duced

energy storage system

costs via a) the

develop

men

t of a

n integration platform

for d

eploying

such batterie

s (Ph

ase 1) and

b) the

use of low

er cost “second

life” ba

tteries in the integrated

platform

(Pha

se 2).

Project scope

being fu

rthe

r evaluated

‐ TB

D

AppA-1

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Pilot F

acilitie

s for New

En

ergy Storage Systems.

Rene

wab

les/DE

R Re

source

Integration

• Th

is project w

ould iden

tify ways to en

hance the existing test lab facilities a

t PG&E’s A

pplied

Techno

logy Services (AT

S) cen

ter to provide lab test and

pilot facilitie

s for new

ene

rgy storage

system

s not previou

sly lab tested

. PG&E’s A

TS lab will be pa

rticularly helpful in working with

the

CEC an

d indu

stry to

test “ne

xt gen

eration” te

chno

logies th

at have the po

tential to make

breakthrou

ghs in cost, p

erform

ance ta

rgets, and

other im

portan

t param

eters, in a te

st grid

en

vironm

ent. Th

is testing wou

ld be a critical step in accelerating commercializa

tion of poten

tial

“gam

e chan

ging” techno

logy. N

ew ty

pes o

f techn

ology that m

ay be tested

at A

TS includ

e, but

are no

t lim

ited to, advan

ced lithium

devices, n

ew so

dium

‐based

system

s, zinc‐air system

s and

ne

w flow

battery che

mistrie

s and

form

ats. The

fund

ing requ

ired to add

full capa

bilities to AT

S is

minim

al. The

costs to

perform

the tests w

ill be pa

id by the indu

stry or b

y en

tities tha

t have

received

research grants from agencies s

uch as th

e CE

C or Dep

artm

ent o

f Ene

rgy (DOE).

N/A

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

source Forecast M

etho

ds

to Better P

redict Variable

Resource Outpu

t

Rene

wab

les/DE

R Re

source

Integration

• De

mon

stratio

n of emerging cap

abilitie

s in mesoscale m

odeling to provide

more gran

ular and

accurate weather fo

recasting inpu

t to Pacific Gas and

Electric Com

pany’s (P

G&E) storm dam

age

pred

ictio

n mod

el, and

to other PG&E forecasting ap

plications, like catastroph

ic wildfire risk an

d Ph

otovoltaic (P

V) gen

eration. The

main goal is m

ore effective an

d gran

ular dam

age pred

ictio

n,

and therefore more efficient re

spon

se to

storm events.

• Project focus is on de

velopm

ent, de

ploymen

t, an

d im

plem

entatio

n of an

operationa

l versio

n of th

e Weather Research an

d Forecasting (W

RF) m

esoscale

mod

el to

supp

ort P

G&E’s forecastin

g program re

lated to fire, storm

s and

solar

prod

uctio

n.• Not in sc

ope for this p

roject are enh

ancemen

ts to

PG&E’s R

estoratio

n Work

Plan other th

an im

proved

forecast dam

age nu

mbe

rs.

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Commun

ication System

s Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Gen

eration Flexibility

Rene

wab

les/DE

R Re

source

Integration

• Th

is project w

ould dem

onstrate th

e use of accep

ted commun

ications protocols to allow th

e Ca

lifornia Inde

pend

ent S

ystem Ope

rator (CA

ISO) to send

an op

erating sig

nal to redu

ce outpu

t un

der spe

cifie

d cond

ition

s, as a

llowed

by contracts.

Project scope

being fu

rthe

r evaluated

‐ TB

D

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

to Ram

p Existing Gas‐Fire

d Gen

eration More Quickly to

Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

Rene

wab

les/DE

R Re

source

Integration

• Th

ere are 33

Gen

eral Electric 7FA

gas tu

rbines installed in com

bine

d cycle configurations in

California, which is con

siderab

ly m

ore than any other tu

rbine mod

el. G

E offers a produ

ct

marketed as “OpFlex Ba

lance” th

at uses a

dvan

ced controls techno

logy to

improve ramp rates to

as high as 40 MW per m

inute (or h

ighe

r in some cases). A

s of O

ctob

er 201

2, non

e of th

e 7FAs in

California were using this prod

uct. Th

is project p

ropo

ses to de

mon

strate im

proved

ramp rate

capa

bilities o

n on

e 7FA so th

at it can se

rve as a m

odel fo

r the

rest of the

7FA

fleet. It is assumed

that th

ere wou

ld be cost sh

are with

the vend

or and

the selected

plant owne

r.

N/A

AppA-2

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

System

Safety an

d Re

liability

through New

Data An

alytics

Techniqu

es

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

velop an

d de

mon

strate a new

data an

alytics techn

ique

to im

prove distrib

ution system

safety and

reliability. The

project sp

ecifically develop

ed and

tested

a System Too

l for Asset Risk

(STA

R), w

hich is an en

terprise software ap

plication that Electric Ope

ratio

ns will use to

calculate

and display (graph

ically and

geo

spatially) risk

scores fo

r electric tran

smiss

ion, su

bstatio

n an

d distrib

ution assets. Th

e STAR

will ena

ble an autom

ated

, system‐w

ide ap

plication to im

prove

risk iden

tification, prio

ritiza

tion, and

investmen

t decision

s to supp

ort e

lectric sy

stem

safety.

• De

mon

strate whe

ther th

e ever‐ in

creasin

g am

ounts o

f data can be

mined

and

combine

d for targeted, cost ‐effective use for improved

asset m

anagem

ent.

• Po

tential scena

rios include

risk‐based

asset m

anagem

ent, safety hazard

mitigatio

n an

d proa

ctive ou

tage prediction using self‐serve an

d virtua

l integration en

vironm

ents.

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for Existing

Tran

smiss

ion & Distrib

ution

Assets: C

lose Proximity

Sw

itching

Grid

Mod

ernizatio

n an

d Optim

izatio

n• Th

is project e

xplores a

nd se

eks to discover effe

ctive, new

tools to safely ope

rate “Solid Blade

in Oil Ro

tatory Switche

s.”

• Test new

tools a

nd te

chniqu

es fo

r safe op

eration of Solid Blade

in Oil Ro

tatory

Switche

s.• Evalua

te alte

rnatives to

decrease prob

ability of injury to workers and

pub

lic.

• He

lp design a robo

tic to

ol to

allow re

mote op

eration.

• De

velop the ne

cessary pa

rts/ad

aptors to

be used

on vario

us ty

pes

(man

ufacturer, bran

d, age, etc.) of Solid Blade

in Oil Ro

tatory Switche

s.

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Remote Mon

itorin

g an

d Co

ntrol Systems for T&D

Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im

prove the Efficacy of

Existing Mainten

ance and

Re

placem

ent P

rogram

s

Grid

Mod

ernizatio

n an

d Optim

izatio

n• Th

e project focus is on de

velopm

ent, testing, dep

loym

ent, an

d im

plem

entatio

n of new

techno

logies, con

struction metho

ds and

techniqu

es, and

cost red

uctio

n techniqu

es in su

pport o

fthe Supe

rviso

ry Con

trol and

Data Ac

quisitio

n (SCA

DA) m

onito

ring system

s used on

the

Distrib

ution Networks. Th

e mon

itorin

g system

con

sists of a com

plex and

exten

sive set o

f compo

nents u

sed to assess the

health

and

con

ditio

n of th

e ne

twork tran

sformers o

n a

continuo

us basis. This research is looking at poten

tial failure points o

n the mon

itorin

g system

compo

nents a

nd wha

t techn

ologies a

nd im

provem

ents can be ap

plied to increase life

expe

ctan

cy of the

se com

pone

nts a

nd re

duce produ

ction an

d mainten

ance costs fo

r this s

ystem

and sim

ilar systems.

• Assess new

techno

logies and

feasibility of a

pplication on

the Distrib

ution

Networks.

• Prim

ary focus o

n techno

logies, com

pone

nts a

nd work metho

ds to

exten

d the

life expe

ctan

cy of m

onito

ring system

s equ

ipmen

t and

redu

ce long te

rm

mainten

ance costs.

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for T&D Assets:

Discrete Series R

eactors

Grid

Mod

ernizatio

n an

d Optim

izatio

n• Gain op

erating expe

rience with

Disc

rete Series R

eactors (DS

R) to

determine whe

ther su

ch

devices w

ould be cost effe

ctive an

d op

erate reliably an

d safely on Pacific Gas and

Electric

Compa

ny’s (P

G&E) tran

smiss

ion system

.

• Install and

test 90 DS

R un

its on the Las P

osita

s‐New

ark 23

0 kV

line

.• Install and

test Server a

t PG&E’s S

an Francisc

o Gen

eral Office (SFG

O)

head

quarters, com

plete with

Smart W

ire System M

anager Softw

are.

• Co

mmun

ication links between the DS

Rs and

server to

supp

ort the

DSR

mon

itorin

g an

d control.

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

velop tools a

nd algorith

ms tha

t ana

lyze data from

mon

itorin

g eq

uipm

ent installed on

substatio

n eq

uipm

ent (distrib

ution an

d tran

smiss

ion) th

at te

sts for diss

olved gasses or o

ther

precursor d

ata that wou

ld assist in und

erstan

ding th

e cond

ition

of the

equ

ipmen

t.

Project scope

being fu

rthe

r evaluated

‐ TB

D

AppA-3

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

velop tools a

nd algorith

ms tha

t ana

lyze load and

ope

ratin

g characteristic data from

un

dergroun

d cables in order to

develop

an un

derstand

ing of poten

tial failure points, cab

le

mainten

ance needs, and

cab

le life expectancy.

Project scope

being fu

rthe

r evaluated

‐ TB

D

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Correctin

g To

ols to Im

prove

System

Records and

Ope

ratio

ns

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

mon

strate to

ols tha

t ide

ntify and

“register” existing assets to

improve the integration

betw

een utility plann

ing an

d op

erations. As part o

f the

dem

onstratio

n, im

plem

ent “self‐

correctin

g” te

chno

logies th

at iden

tifies p

lan vs. actua

l disc

repa

ncies a

nd upd

ates sy

stem

records

automatically. High prio

rity use cases include

: (1) M

apping of transform

ers to prim

ary ph

ase;

(2) M

apping of customers to tran

sformers; and

(3) P

recisio

n map

ping of P

acific Gas and

Electric

Compa

ny’s overhead an

d un

dergroun

d ne

twork.

Project scope

being fu

rthe

r evaluated

‐ TB

D

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Techno

logies th

at Im

prove

Wildlife Safety and

Protect

Assets from

Weather‐

Related De

grad

ation

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

mon

strate new

strategies and

techno

logies to

improve an

imal and

bird

protection, re

duce

outages c

aused by animals a

nd bird

s, and

protect assets from expen

sive weather re

lated

degrad

ation such as fog re

lated corrosion.

Project scope

being fu

rthe

r evaluated

‐ TB

D

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Co

mmun

ication System

s to

Improve Substatio

n Au

tomation an

d Interope

rability

Grid

Mod

ernizatio

n an

d Optim

izatio

n• De

mon

strate new

strategies and

techno

logies to

con

vert and

integrate multip

le existing

prop

rietary te

chno

logies with

in th

e substatio

n en

vironm

ent for m

ore effective op

erations.

Substatio

n are key op

erationa

l hub

s and

represen

t significan

t investm

ents, w

hich m

ust b

e furthe

r leveraged

by en

gaging with

ven

dors to

create the ne

xt gen

eration of interope

rable

substatio

n services and

produ

cts.

Project scope

being fu

rthe

r evaluated

‐ TB

D

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Gen

eration" SmartM

eter™

Telecom Network

Functio

nalities

Grid

Mod

ernizatio

n an

d Optim

izatio

n• Th

is project e

xplores a

nd disc

overs e

ffective ne

w network ap

plications and

devices to

leverage and

improve the Sm

artM

eter™ com

mun

ications network.

• Leverage th

e existing Sm

artM

eter™ network to su

pport a

ddition

al

applications. Inform

future uses o

f the

SmartM

eter™ network such as m

essage

capa

bility, se

curity, latency, and

engineerin

g constraints. Spe

cifically fo

cus o

n:‐ T

est n

ew devices to

supp

ort n

etwork functio

ns and

cap

abilitie

s not previou

sly

envisio

ned (e.g., ne

w data stream

s, fa

ster data collection).

‐ Evaluate alternatives to

decrease future upgrade

, mainten

ance and

/or

operationa

l costs.

‐ Dem

onstrate differen

t network ap

plications, each focused on

sepa

rate use

cases.

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Techno

logies and

Strategies

That Sup

port In

tegrated

"Customer‐to‐Market‐to‐

Grid

" Ope

ratio

ns of the

Future

Grid

Mod

ernizatio

n an

d Optim

izatio

n• Th

e ob

jective of th

is pilot is to de

velop an

d pilot a

real‐tim

e da

ta visu

aliza

tion software

platform

for u

se by Electric Distrib

ution Ope

ratio

ns end

users. Da

ta will be integrated

from

vario

us data sources a

nd disp

layed on

Distrib

ution Co

ntrol Cen

ter v

ideo

walls an

d individu

al

desktop compu

ters, w

ith poten

tial for fu

ture sc

alab

ility to

han

dheld de

vices.

• Scop

e includ

es th

e integration of data (network mod

el, loa

ding, SmartM

eter™

devices, outages, w

eather, etc.) an

d a real‐tim

e da

ta visu

aliza

tion platform

for

Distrib

ution Ope

ratio

ns.

• Th

e Distrib

ution Man

agem

ent S

ystem (D

MS) platform and

predictive an

alytics

are no

t include

d in th

e scop

e.

AppA-4

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Vehicle as a Resou

rce to

Improve Grid

Pow

er Qua

lity

and Re

duce Customer

Outages

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Leverage plug‐in hybrid

veh

icle te

chno

logy emerging in Pacific Gas and

Electric Com

pany

(PG&E) fleet to gene

rate utility

‐grade

pow

er, sup

porting distrib

ution circuits during plan

ned

unplan

ned ou

tage events.

or • De

velop no

minally 120

kilowatt e

xportable po

wer cap

abilitie

s from a plug in

hybrid electric truck. Seek to create the protocols n

ecessary to

safely con

nect

the truck to th

e ap

prop

riate grid

con

nection po

ints. Th

e po

rtfolio of fleet

vehicles (h

ighe

r and

lower weight classes) m

ay broad

en th

e range of available

power ra

tings dem

onstrated by th

e project.

201st T

rienn

ial (20

12‐201

4)PG

&E

1.17 ‐ Leverage EPIC Fund

s by Participating in M

ulti‐

Utility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

Grid

Mod

ernizatio

n Optim

izatio

nan

d • PG

&E can leverage EPIC do

llars by pa

rticipating an

d collabo

ratin

g in m

ulti‐utility indu

stry‐w

ide

research initiatives con

ducted

by third

party organ

izatio

ns experienced

in th

e RD

&D area. The

se

programs w

ould allow PG&E to cost e

ffectively de

velop a de

eper awaren

ess o

f ind

ustry tren

ds,

access re

al world experience through pilot p

rogram

s, and

iden

tify the gaps th

at utilities will fill

or close with

techno

logy. For example, th

rough pa

rticipation in existing EP

RI program

s, PG&E

wou

ld participate in and

gain access to

dem

onstratio

ns, ana

lyses, and

results of the

testing an

d stud

y of distrib

ution eq

uipm

ent a

nd strategies. H

igh Va

lue EP

RI program

s include

: IntelliG

rid,

Integration of Distrib

uted

Ren

ewab

les, Ene

rgy Storage, Risk

Mitigatio

n Strategies, and

Distrib

ution Grid

Mod

ernizatio

n programs.

Project scope

being fu

rthe

r evaluated

‐ TB

D

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

SmartM

eter™‐Ena

bled

Data

Analytics to Provide

Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

Custom

er Service

Enab

lemen

tan

d • Th

is project focuses on de

livering the cost by major app

liances to

customers.

• Th

is project w

ill use th

e da

ta ena

bled

by the Sm

artM

eter™ platform to

provide

appliance level itemiza

tion of m

onthly bill cha

rges to

customers, with

out the

ir completing an

y au

dit o

r sub

scrib

ing to any new

service. This p

roject assum

es

that m

inute level m

eter data is available.

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Techniqu

es and

Cap

abilitie

s via the Sm

artM

eter™

Platform

Custom

er Service

Enab

lemen

tan

d • Th

e project is to explore an

d discover effe

ctive, new

data that can be collected

and

stud

ied

furthe

r ben

efits. De

mon

strate th

e type

of a

ddition

al data that can be collected

and

/or

processed through the Sm

artM

eter™ platform. Evalua

te im

pact of a

ny increased da

ta traffic

the Sm

artM

eter™ network. Focus on ne

w data collection that m

akes th

e Sm

artM

eter™

for

on •

Demon

strate th

e collection of new

data from

SmartM

eter™ devices. Exam

ple

use cases include

:‐ P

ower Qua

lity Da

ta (C

12.19 form

at).

‐ New

Data Ch

anne

ls.platform

more robu

st fo

r more custom

ers.

‐ Mob

ile data collection metho

ds.

‐ Pow

er th

eft d

etectio

n metho

dology usin

g Sm

artM

eter™ data for reven

ue

assurance pu

rposes.

AppA-5

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Be

nefits o

f Providing th

e Co

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er‐Autho

rized

Sm

artM

eter™ Data to Driv

e Inno

vatio

n.

Custom

er Service

Enab

lemen

tan

d • Th

is project w

ill fu

nd con

tinue

d supp

ort o

f Green

Button Co

nnect (GBC

). GBC

provide

s a sm

all

numbe

r of ven

dors in th

e compe

titive market w

ith autom

ated

access to recurring, m

achine

‐to‐

machine

, program

matic data access to

customer‐autho

rized

SmartM

eter™ data in order to

de

velop ne

w, inn

ovative an

d creativ

e ways for customers to man

age their e

nergy consum

ption.

GBC

is a sm

all dem

onstratio

n, not sc

alab

le to

supp

ort the

larger customer base an

d wider

vend

or aud

ience. PG&E is plan

ning on im

plem

entin

g a robu

st, b

road

er sc

ale offerin

g as part o

f its Customer Data Ac

cess (C

DA) p

roject.

N/A

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Au

tomatic Id

entification of

Distrib

uted

Ene

rgy Re

sources

(Such as Solar PV) as T

hey

Intercon

nect to

the Grid

to

Improve Safety & Reliability

Custom

er Service

Enab

lemen

tan

d • Th

is project a

ims to validate an

d integrate a software platform

to iden

tify ph

otovoltaic (P

V)

resources b

y leveraging Smart M

eter™ data. This p

roject fo

cuses o

n ad

dressin

g the iss

ue of

unau

thorize

d intercon

nections in an au

tomated

fashion by develop

ing an

d algorithm

to iden

tify

resources, includ

ing integration with

Pacific Gas and

Electric Com

pany (P

G&E) billing an

d intercon

nection da

taba

se, as w

ell as d

evelop

an au

tomated

outreach system

for ide

ntified

custom

ers.

• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, R

.11 09

011

Rule 21

to su

pport the

improved

distrib

ution level interconn

ectio

n rules a

nd re

gulatio

ns fo

r certain

classes o

f electric gen

erators a

nd electric storage resources.

• Iden

tify vend

or to

develop

or p

ilot softw

are.

• De

velop integration an

d commun

ication platform

for a

uto iden

tification

Una

utho

rized

Intercon

nections (U

I).• De

mon

strate ability to autom

atically integrate software with

billing an

d intercon

nection.

of

251st T

rienn

ial (20

12‐ 201

4)PG

&E

1.22 ‐ De

mon

strate

Subtractive Billing W

ith

Subm

etering for E

Vs to

Increase Customer Billing

Flexibility

Custom

er Service

Enab

lemen

tan

d • EV

subm

etering pilot to test su

btractive metering process a

nd Electric Veh

icle Service Provide

r (EVS

P) business m

odels.

• Th

is project a

ddresses CPU

C D.13

‐11‐00

8, which re

quire

s Pacific Gas and

Electric Com

pany

(PG&E), along with

the othe

r two Ca

lifornia Investor Owne

d Utilities (IOU), to pursue a

subm

etering pilot a

nd eventua

l protocol.

• Electric Veh

icle (E

V) su

bmetering pilot w

ill entail EV Meter Data Man

agem

ent

Agen

ts (M

DMA) delivering subm

eter data to IO

U fo

r sub

tractio

n from

custom

er’s prim

ary meter to

create an EV an

d a ho

use bill. Customer will be

respon

sible fo

r both bills. In Pha

se 2, an ad

ditio

nal business m

odel will be

introd

uced

whe

re th

e MDM

A will be respon

sible fo

r the

bill to

PG&E.

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive

Billing W

ith Sub

metering for

PVs to Increase Customer

Billing Flexibility

Custom

er Service

Enab

lemen

tan

d • Initiative to obtain ad

ditio

nal un‐ne

tted

Pho

tovolta

ic (P

V) data to su

pport customer call cen

ter

bill expe

rience, and

provide

add

ition

al se

rvice to its c

ustomers. PV gene

ratio

n da

ta will be

integrated

with

existing MyEne

rgy web

portal for customers’ ben

efit.

• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, N

et Ene

rgy Metering

R.12

‐11‐00

5 an

d R.11

09 01

1 Ru

le 21.

• Explore fo

ur differen

t metho

ds fo

r obtaining PV gene

ratio

n da

ta (D

edicated

Sm

artM

eter™, sub

meter com

mun

ication via ZigB

ee ra

dio, th

ird party estim

ates,

and da

ta excha

nge with

solar com

panies, and

work with

ven

dor to relay da

ta to

custom

er.

AppA-6

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Side

Man

agem

ent (DS

M) for

Tran

smiss

ion an

d Distrib

ution (T&D) Cost

Redu

ction

Custom

er Service

Enab

lemen

tan

d • Assess how

to best u

tilize

DSM

resources to create a ta

rgeted

customer‐ a

nd locatio

n‐specific

approa

ch to

assist with

distrib

ution capa

city con

straints.

• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, D

istrib

ution

Resources P

lann

ing R.14

08 01

3, th

rough im

proving efficiencies b

etween intercon

nection an

d integration.

• Im

prove ab

ility to

estim

ate He

ating, Ven

tilation an

d Air C

onditio

ning (H

VAC)

Direct Loa

d Co

ntrol (DL

C) load im

pacts a

t the

distrib

ution feed

er level to aid in

better und

erstan

ding of the

localized

impa

ct of H

VAC DL

C de

vices o

n meetin

g distrib

ution feed

er level reliability concerns.

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map

The Preferred Locatio

ns fo

r DC

Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

Custom

er Service

Enab

lemen

t and

• De

velop, pilot, an

d validate ap

proa

ches th

at help de

term

ine the op

timal

chargers based

on traffic patterns a

nd distrib

ution grid infrastructure.

locatio

n of DC fast

• Ac

quire

travel pattern data an

d grid infrastructure cap

ability data to iden

tify

low cost, high utiliza

tion areas in which to

integrate DC

fast cha

rgers into Pacific

Gas and

Electric Com

pany’s (P

G&E) distrib

ution system

.

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t an

d Telemetry Strategies a

nd

Techno

logies Tha

t Ena

ble the

Cost‐Effe

ctive Integration of

Mass M

arket D

eman

d Re

spon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Custom

er Service

Enab

lemen

t and

• De

velop, dem

onstrate and

validate ap

proa

ches and

techno

logies th

at ena

ble the cost

effective integration (spe

cifically, the

measuremen

t and

telemetry) o

f mass m

arket D

R resources into the Ca

lifornia Inde

pend

ent S

ystem Ope

rator (CA

ISO) w

holesale m

arket. W

hile

othe

r DR projects fo

cus o

n integration of DR resources into vario

us utility

and

future

Inde

pend

ent S

ystem Ope

rator o

peratio

nal needs, this p

roject intend

s to test alte

rnative

telemetry so

lutio

ns and

techno

logies to

satisfy CAISO

ope

ratio

nal visibility requ

iremen

ts.

Project scope

being fu

rthe

r evaluated

‐ TB

D

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage

the Distrib

ution Grid

on

Rene

wab

les/DE

R Integration

Resource

• Iden

tify an

d evalua

te whe

ther sy

stem

storage, includ

ing iden

tifying a ra

nge of

requ

iremen

ts on a gran

ular level.

need

s can be cost‐effe

ctively ad

dressed with

ene

rgy

storage de

ploymen

t locations and

grid

intercon

nection

TBD

AppA-7

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

Demon

strate new

techno

logy to

mon

itor a

nd con

trol Distrib

uted

Ene

rgy Re

sources (DE

R) to

man

age system

con

straints and

evaluate the po

tential value

of D

ER flexibility to

the grid. The

DE

RMS pilot w

ill driv

e learning abo

ut th

e pe

ople, p

rocess, and

techno

logy neede

d to ope

rate

the high DER

pen

etratio

n grid of 2

025.

• De

fine bo

unda

ries a

nd integrations with

other PG&E an

d external sy

stem

s such as Dem

and

Respon

se M

anagem

ent S

ystem (D

RMS), A

dvan

ced Distrib

ution Man

agem

ent S

ystem (A

DMS)

and CA

ISO m

arket systems a

mon

g othe

rs.

• En

able inform

ed cho

ice for lon

g‐term

strategic vend

or in 201

7+ (d

emon

stratio

n is no

t choo

sing the long te

rm ven

dor).

• Iden

tify lim

itatio

ns of e

xisting as‐built mod

els a

nd field telemetry data

• Evalua

te th

e pe

rforman

ce of a

ggregated DE

Rs providing distrib

ution services

• Create, test, an

d ite

rate on future DER

MS requ

iremen

ts (e

.g., commun

ication requ

iremen

ts

for P

G&E an

d third

party owne

d DE

Rs).

• Learn ab

out b

usiness p

rocess cha

nge an

d pe

rson

nel skills & kno

wledge ne

eded

to im

plem

ent

DERM

S.• Th

is project informs C

alifo

rnia Pub

lic Utilities Com

miss

ion proceeding, D

istrib

ution Re

sources

Plan R.14 08

013

to inform

distrib

ution plan

ning by de

mon

stratin

g DE

R integration into plann

ing

and op

erations.

• De

mon

strate m

inim

um viable DE

RMS op

eration at Pacific Gas and

Electric

Compa

ny (P

G&E) to

add

ress key DER

man

agem

ent u

se cases.

• Th

e de

mon

stratio

n will ta

ke place in a limite

d geograph

y with

a diverse se

t DE

Rs being m

onito

red an

d controlled by th

e DE

RMS de

mon

stratio

n.of

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

• Th

is project w

ill explore th

e use an

d im

pact of a

ggregated custom

er‐site

d sm

art inverters to

he

lp inform

emerging indu

stry stan

dards, as w

ell as d

efine the op

erationa

l and

com

mun

ication

requ

iremen

ts to

supp

ort the

advan

cemen

t and

dep

loym

ent o

f new

inverter te

chno

logies.

• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, D

istrib

ution

Resources P

lan R.14

08 01

3, by inform

ing Distrib

uted

Ene

rgy Re

sources m

odeling by

incorporating Sm

art Inverters. The

find

ings of this rep

ort w

ill also

supp

ort a

nd inform

PG&E’s

position with

in th

e Ru

le 21 op

en proceed

ing.

• Th

is project leverages th

e results of the

lab testing of sm

art inverter

functio

nalities tha

t is b

eing com

pleted

by PG

&E's S

mart G

rid Pilot V

olt/Va

r Optim

izatio

n (VVO

) Project at P

G&E’s A

pplied Techno

logies Services (AT

S) Lab

(as s

pecifie

d by th

e Sm

art Inverter W

orking Group

).• Th

is EP

IC project will dep

loy sm

art inverters on on

e or m

ore feed

ers to

evalua

te th

eir e

ffectiven

ess in im

proving PV

integration, su

pportin

g an

d mitigatin

g grid needs and

safety risks.

AppA-8

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Vehicle to Hom

e

Rene

wab

les/DE

R Integration

Resource

• Assessmen

t of the

inverter assessm

ent related

to Pho

tovolta

ics (PV

) in project 2

.03A

. Smart Inverters fo

r PV

use an

d im

pact of E

V en

ergy flow

cap

abilitie

s as a

com

plem

ent to the sm

art• Techn

ology de

mon

stratio

n for cha

rging an

d discha

rging of th

e Electric Veh

icle

(EV) in re

spon

se to

dem

and respon

se or h

ard islan

ding events.

• Testing multip

le te

st m

odes.

• Techno

logy assessm

ent from customer and

ratepa

yer p

erspectiv

es th

rough a

custom

er su

rvey and

a cost‐be

nefit evaluation.

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g Vo

ltage Tracking

&

Rene

wab

les/DE

R Integration

Resource

• Utiliza

tion of th

e volta

ge m

easuremen

t cap

abilitie

s of SmartM

eter™ devices to

mon

itor

Distrib

uted

Gen

eration (DG) o

utpu

t and

iden

tify volta

ge fluctuations cau

sed by th

e interm

itten

t na

ture of d

istrib

uted

rene

wab

le re

sources.

• Create

violation an algorith

mic process outpu

t rating on

the likelihoo

d of a

(on a given tran

sformer) b

eing cau

sed by DG fluctuations.vo

ltage

• Use of d

ata an

alytics techn

ique

s and

Advan

ced Metering Infrastructure (A

MI) (and

other) d

ata

to determine the im

pact of P

V pe

netration on

Rule 2 violations and

• Create a ra

ting for the

proba

bility that a Rule 2 violation is caused

by DG

.

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Emulation for D

G Im

pact

Improvem

ent

Rene

wab

les/DE

R Integration

Resource

• De

mon

strate th

e capa

bility to emulate inertia

injection an

d supp

ort p

rimary freq

uency control

using en

ergy storage an

d sm

art inverter techn

ologies to po

tentially m

itigate th

e im

pacts o

f large‐scale Distrib

uted

Gen

eration (DG) to the grid, improve the grid perform

ance and

reliability, and

advan

ce Califo

rnia ene

rgy po

licy to increase th

e am

ounts o

f ren

ewab

le and

distrib

uted

gen

eration on

the grid.

• De

velop compu

ter m

odels to evalua

te inverter cap

abilitie

s and

dem

onstrate

possible fu

ture sy

stem

needs fo

r new

inertia

supp

ort solutions.

• An

alyze an

d op

timize

the presen

t techn

ology’s e

nergy storage inertia

l respon

se cap

abilitie

s via Pow

er‐Hardw

are‐In‐Loo

p testing.

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AppA-9

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

362n

d Trienn

ial (20

15‐201

7)PG

&E

2.06 ‐ Intelligent Universal

Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

• De

velop an

d de

mon

strate a so

lid‐state tran

sformer field prototype Med

ium Voltage Fast

Charger (MVF

C) sy

stem

, as a

n ap

plication use case of solid‐state tran

sformers for Dire

ct Current

(Dire

ct Current) fast cha

rging of Plug In Electric Veh

icles (PE

V), featurin

g intelligent con

trols a

nd

multip

le fa

st cha

rging of PEV

s.

• Test dem

onstratio

n tran

sformer with

two an

d commun

ication

protocols.

to th

e same DC

solid‐state

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Th

is de

mon

stratio

n will leverage interval data to im

prove feed

er m

odeling, inform

near real

time load allocatio

n througho

ut th

e distrib

ution grid and

tran

sformer load

ing profiles, and

iden

tify op

portun

ities to

enh

ance current load fo

recasting processes for distrib

ution

tran

sformers, fe

eders a

nd su

bstatio

n tran

sformers.

• Utilize

AMI and

other data sources to de

velop an algorith

m to

improve the

pred

ictio

n of grid

load

ing.

• De

mon

strate th

e aggregation of th

is load

ing up

through the distrib

ution

mod

el to

enh

ance distrib

ution plan

ning as w

ell as real tim

e distrib

ution grid

operations.

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

mon

strate strategies and

techno

logies fo

r real tim

e, online mon

itorin

g of su

bstatio

n eq

uipm

ent; De

mon

strate com

mun

ication protocols a

nd equ

ipmen

t to supp

ort the

smart

devices; Develop

visu

aliza

tion techniqu

es fo

r improved

mon

itorin

g; and

evaluate ne

w ven

dor

techno

logies th

at ena

ble da

ta correlatio

n an

d pred

ictiv

e an

alysis to better ide

ntify and

respon

d to poten

tial safety, re

liability an

d/or ope

ratio

nal issue

s.

TBD

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

mon

strate con

gestion mitigatio

n by installing DS

Is on pa

rallel transmiss

ion facilities to

demon

strate th

e ne

xt gen

eration of th

e Distrib

uted

Series R

eactor (D

SR) d

evices from

the First

EPIC Trie

nnial Plan, which m

ay allow fo

r better con

trol of transmiss

ion line load

ing.

TBD

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Incorporate na

tural hazard da

mage mod

el inform

ation into one

integrated

algorith

m/too

l, which wou

ld provide

the ab

ility to

quickly estim

ate the im

pacts o

f natural hazards on Pacific Gas

and Electric Com

pany fa

cilities to en

able fa

ster re

spon

se and

restoration.

• Provide the ab

ility to

prepa

re fo

r the

se hazards by proa

ctively mod

eling the im

pacts o

f po

tential hazards, to un

derstand

system

vulne

rabilities a

nd re

storation resource re

quire

men

ts.

• Incorporate work op

timiza

tion algorithm

s to more efficiently allocate crews.

• Utilize

artificial intelligence an

d statistical m

etho

ds to

mod

el produ

ctive rates a

nd

automatically develop

restoration plan

s.

• De

velop op

timiza

tion algorithm

s and

visu

aliza

tion tool th

at includ

es asset

locatio

ns and

con

ditio

ns with

multip

le poten

tial hazards, w

hich allows for th

e aggregation of equ

ipmen

t dam

age estim

ates (via dam

age mod

els, outage

inform

ation system

s, and

dam

age assessmen

ts), est. ho

urs to repa

ir, and

recommen

ded allocatio

n of work resources to efficiently re

spon

d to a natural

hazard.

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

mon

strate ta

ilored, advan

ced mob

ile app

lications fo

r Pacific Gas and

Electric Com

pany field

operations th

at build upo

n Grid

Ope

ratio

ns Situ

ationa

l Intelligen

ce (P

roject #15

) dem

onstratio

n projects in th

e EP

IC First T

rienn

ial Plan as well as e

xisting “baseline” m

obile dep

loym

ents

unde

rway.

TBD

AppA-10

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Man

agem

ent M

obile

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

velop ne

w m

obile app

lications to

enh

ance

prep

ared

ness and

respon

se cap

abilitie

s.Pacific Gas and

Electric Com

pany’s emergency

TBD

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Substatio

n/Substatio

n Au

tomation

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Investigate an

d evalua

te su

staina

ble protectio

n an

d control techn

ologies for fu

ture “digital”

substatio

ns, w

hich m

ay includ

e testing techno

logies in a lab setting, and

perform

ing a pilot

implem

entatio

n to dem

onstrate te

chno

logy ado

ption an

d integration with

legacy su

bstatio

n protectio

n an

d control techn

ologies.

TBD

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically

Phasing Inform

ationMap

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Th

is project a

ims

automatically m

ap

netw

ork mod

els.

to explore a variety of p

re‐com

mercial ana

lytics a

nd/or h

ardw

are op

tions

3‐ph

ase electrical pow

er inform

ation in order to

improve the distrib

ution to •

Project

map

ping se

eks to im

prove distrib

ution ne

twork mod

els

of 3 pha

se electric

al pow

er inform

ation.

through au

tomatic

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Applications fo

r Gen

erator

Dyna

mic M

odel Validation

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Th

is project w

ill dem

onstrate new

synchrop

hasor a

nalysis app

lications th

at can perform

gene

rator d

ynam

ic m

odel param

eter estim

ation an

d validation using disturba

nce da

ta re

corded

by th

e synchrop

hasor system. New

synchrop

hasor a

pplications cou

ld perform

man

dated

gene

rator m

odel validation with

out req

uirin

g tim

e and

labo

r inten

sive on

‐site

tests, and

cou

ld

detect su

bsynchrono

us re

sona

nce an

d othe

r con

ditio

ns which can cau

se gen

erator outages.

• Scop

e is lim

ited to con

firming that ana

lysis of P

hasor M

easuremen

t Unit

(PMU) d

ata is be

tter th

an costly

on‐site mod

el validation in th

e target

geograph

y. Scope

doe

s not includ

e widespread de

ploymen

t of P

MUs.

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Synchrop

hasor A

nalytics

Applications

&

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

mon

strate new

techniqu

es to

synthe

size Synchrop

hasor d

ata an

d utilize th

e da

ta fo

r ad

vanced

real‐tim

e system

app

lications, such as wide‐area m

onito

ring, protection, and

con

trol

system

s, which cou

ld help move Synchrop

hasor a

pplications beyon

d plan

ning, foren

sics, and

visualiza

tion to enh

anced wide‐area m

onito

ring, protection, and

con

trol app

lications.

TBD

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Disturba

nce (GMD)

Evalua

tion

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Evalua

te sy

stem

vulne

rability to GMD by m

odeling GMD that occurs d

uring

storm and

evaluating the im

pact on tran

smiss

ion lines, interconn

ectio

n lines,

system

voltages.

a geom

agne

tic

substatio

ns and

TB

D

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Tran

sformers a

nd Sen

sors

Protectio

n an

d Co

ntrol

System

s

for Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

mon

strate new

er te

chno

logies, such as optical se

nsors, as w

ell as s

trategies a

nd

techno

logies to

con

figure ap

prop

riate protection settings, including th

e coordina

tion

betw

een bo

th new

and

con

ventiona

l instrum

entatio

n.requ

ired

TBD

AppA-11

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

De

man

d‐Side

Strategies &

Techno

logies

Custom

er Service

Enab

lemen

tan

d • De

mon

strate distrib

uted

ene

rgy storage an

d ap

proa

ches to

add

ress local and

flexible re

source

need

s.• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, D

istrib

ution

Resources P

lan R.14

08 01

3, by de

mon

stratin

g DE

R locatio

nal ben

efits and

add

ressing capa

city

constraints throu

gh aggregated be

hind

the meter (B

TM) customer ene

rgy storage.

• De

ploy an aggregation of BTM

customer ene

rgy storage resource to

pe

ak load

ing or absorb distrib

uted

gen

eration on

a utility

distrib

ution redu

ce

feed

er(s).

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e Usage Feedb

ack

Custom

ers

Energy

to

Custom

er Service

Enab

lemen

tan

d • Evalua

te inno

vativ

e feed

back te

chno

logies to

provide

near real‐tim

e en

ergy usage

inform

ation to customers a

nd to

driv

e greater customer perform

ance during DR

events.

TBD

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

(HAN

) for Com

mercial

Custom

ers

Custom

er Service

Enab

lemen

tan

d • Th

is project w

ill dem

onstrate th

e Co

mpa

ny’s com

mercial customers.ap

plication of HAN

techno

logy to

Pacific Gas and

Electric

• Th

is project w

ill ena

ble the Zigbee HAN

radio on

Large Com

mercial and

Indu

stria

l (LCI) meters, to

facilitate LCI customer access to real time usage da

ta,

as well as testin

g of th

e integration with

existing En

ergy M

anagem

ent S

ystems

(EMS).

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

through Targeted

Data

Analytics

Custom

er Service

Enab

lemen

tan

d • Iden

tify strategic custom

ers a

nd ta

rget dem

and redu

ction in local areas by combining and

integrating multip

le Dem

and Side

Man

agem

ent techn

ologies (e.g., Ene

rgy Efficiency (EE),

Deman

d Re

spon

se (D

R), D

istrib

uted

Ene

rgy Storage, Con

sumer orie

nted

Ene

rgy To

ols).

• Investigate whe

ther Pacific Gas and

Electric Com

pany can achieve a su

fficien

t amou

nt of

deman

d redu

ction through visib

ility into th

e custom

er‐side resources, and

improve the

reliability of customer‐side resources a

t the

local level in order to

resche

dule local cap

acity

expa

nsion expe

nditu

res.

• Th

is project a

ddresses Califo

rnia Pub

lic Utilities Com

miss

ion proceeding, D

istrib

ution

Resources P

lan R.14

08 01

3, by supp

ortin

g the fair an

d tran

sparen

t processes fo

r Distrib

uted

En

ergy Resou

rce (DER

) dep

loym

ent a

nd integration.

• De

velop a solutio

n/tool th

at determines neede

d custom

er dem

and redu

ction

individu

ally and

in aggregate at a

sset level, leveraging interval and

Sup

ervisory

Control and

Data Ac

quisitio

n (SCA

DA) d

ata.

• De

velop cross D

ER customer ta

rgeting to add

ress fo

recasted

cap

acity

challenges at spe

cific assets, fo

r spe

cific days a

nd times of year, leveraging

interval data an

d othe

r customer attrib

utes.

AppA-12

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

532n

d Trienn

ial (20

15‐201

7)PG

&E

2.23 ‐ Integrate De

man

d Ap

proa

ches In

to Utility

Plan

ning

Side

Customer Service

Enab

lemen

tan

d • Th

is project w

ill enh

ance Pacific Gas and

Electric Com

pany’s ability to incorporate the grow

ing

usage of Distrib

uted

Ene

rgy Re

sources (DE

R) into distrib

ution plan

ning to

ols b

y de

veloping new

custom

er class load sh

apes th

at incorporate DE

Rs, and

a m

etho

dology fo

r mod

eling DE

R de

ploymen

t uncertainty at the

circ

uit level.

• Th

e execution of th

is project a

ddresses issues as ide

ntified

in th

e following proceedings:

Distrib

ution Re

sources P

lan R.14

‐08‐01

3 an

d Assembly Bill 32

7 Section 76

9, which re

quire

s tran

sparen

t and

con

sistent m

etho

ds to

integrate cost effe

ctive DE

Rs into th

e distrib

ution

plan

ning process.

• Integrate a broa

der ran

ge of customer‐side techno

logies and

DER

app

roache

s into grid

plann

ing an

d op

erations in a least cost framew

ork by enh

ancing

distrib

ution load fo

recasting tools to includ

e ne

w customer load sh

apes based

on

the usage of DER

s and

to m

odel th

e un

certainty of DER

dep

loym

ent a

t the

circuit level.

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Disaggregatio

n for N

on‐

Resid

entia

l Customers

Custom

er Service

Enab

lemen

tan

d • De

mon

strate th

e ab

ility to

use su

b‐minute

load fo

r non

‐residen

tial customers.

level usage inform

ation to determine ap

pliance

TBD

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart

Commun

ications

Grid

Cross‐Cu

tting/Foun

datio

nal

• Evalua

te license spectrum

provide

rs th

at

Commun

ications Com

miss

ion (FCC

) licen

se ha

ve develop

ed te

chno

logies

freq

uency range/spectrum

.offered on

the Fede

ral TB

D

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Distrib

ution Au

tomation

Ope

n Archite

cture De

vices

Cross‐Cu

tting/Foun

datio

nal

• De

mon

strate th

e means by which new

customer and

distrib

ution de

vices c

ould interope

rate

with

Pacific Gas and

Electric Com

pany’s Advan


MI) ne

twork (IP

v6).• De

mon

strate th

e metho

dology, p

rotocols, and

stan

dards

vend

ors to conn

ect a

nd com

mun

icate vario

us new

devices

(e.g., Ho

me Area Network, Electric Veh

icle cha

rging, sm

art

the AM

I network (IP

v6) in an effe

ctive man

ner.

for customers a

nd

and ap

plications

appliances, etc.) with

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Integrated

Smart G

rid

Network Man

agem

ent

Cross‐Cu

tting/Foun

datio

nal

• Evalua

te new

techno

logies to

holistically m

onito

r, control and

evolve the commun

ications

netw

ork an

d supp

ortin

g infrastructure as a

platform to

ena

ble Sm

art G

rid so

lutio

ns.

• De

mon

strate a new

Advan


MI) Network

man

agem

ent system to

holistically m

onito

r, control, an

d evolve th

e existing

AMI n

etwork an

d infrastructure from

a billing‐centric platform to

a fu

lly

operationa

l AMI solutions platform th

at will m

eet e

volving custom

er and

grid

ne

eds.

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Commun

ications

Mon

itorin

gPath

Cross‐Cu

tting/Foun

datio

nal

• Evalua

te com

mun

ication pa

ths for AMI related

messages, includ

ing metho

ds to

interferen

ce, con

gestion, validate prop

er autho

rizations, and

grant clearan

ces for

message over a

secured commun

ication pa

th.

clear p

oten

tial

send

ing

• De

term

ine the ab

ility to

iden

tify, ana

lyze, and

diagnose Ra

dio Freq

uency

interferen

ce th

at can occur along th

e commun

ication pa

th from

the meter

through the da

ta collectors to the AM

I ven

dors’ con

trol sy

stem

.

AppA-13

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

Administrator

AB

CD

E1E2

For

Repo

rt

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv.Scope

DOC

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile M

eter

Cross‐Cu

tting/Foun

datio

nal

• De

mon

strate th

e utility’s ability to ena

ble dyna

mic electric m

obile m

etering.

• De

velop an

d test a m

obile m

eter prototype

on vario

us app

lications th

at can be

Applications

used

to cap

ture and

mon

itor real‐tim

e en

ergy tran

sactions and

usage (e

.g. Plug‐

In Electric Veh

icles (PE

V), D

istrib

uted

Gen

eration (DG), mob

ile storage, etc.).

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to Grid

Mod

ernizatio

n an

d • Leverage EPIC do

llars by pa

rticipating an

d collabo

ratin

g in m

ulti‐utility, ind

ustry wide

TBD

Participate in In

dustry‐W

ide

Optim

izatio

nresearch, dem

onstratio

n an

d de

ploymen

t initia

tives con

ducted

by third

party organ

izatio

ns.

RD&D Programs

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐

Rene

wab

les/DE

R Re

source

• De

mon

strate how

aggregated be

hind

‐the

‐meter ene

rgy storage system

s tha

t are ope

rated by N

/ATh

e‐Meter Storage M

arket / Integration

a third

party disp

atcher m

ay add

ress who

lesale m

arket n

eeds, w

hile also

ope

ratin

g as a

Retail Optim

izatio

ncustom

er re

source to

redu

ce customers’ re

tail electric bills.

AppA-14

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


eBrief D

escriptio

n of th

e Project ‐ Scope

AB

CD

E1E2

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

iii. O

bjectiv

eiv. Scope

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

• Evalua

te

assess th

e grid im

pacts from Electric Veh

icle (E

V) cha

rging used

for

ability to

man

age the resulting load usin

g activ

e de

man

d ridesha

ring ap

plications,

man

agem

ent.

to N/A

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service Issue

Iden

tification Leveraging

Mom

entary Outage

Inform

ation

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Leverage m

ultip

le so

urces o

f data, includ

ing bu

t not limite

d to SmartM

eter™, tim

e of

locatio

n an

d weather data, to

proactiv

ely iden

tify po

tential problem

s in the Electric

Tran

smiss

ion an

d Distrib

ution (T&D) sy

stem

, spe

cifically re

lated to iden

tifying locatio

ns

high incide

nces of m

omen

tary outages which m

ay be caused

by im

minen

t failures o

f cond

uctors, insulators, tran

sformers a

nd/or v

egetation contact.

day,

with

N/A

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Integrate ad

ditio

nal sen

sing techno

logy into com

mun

icating “smart” line

sensors a

nd

demon

strate th

e ab

ility to

use th

at Line Sensor platform to

mon

itor the

grid

and

possib

ly

potential outages.

pred

ict•

Assess te

chnical feasib

ility and

poten

tial sen

sor ran

ge to

validate op

portun

ity

for b

usiness b

enefits.

• Work with

SMEs to

develop

best solution archite

cture for integratin

g RF

sensor produ

ct into line

sensors.

• Integrate line sensor with

add

ition

al se

nsing capa

bility an

d set u

p ph

ysical te

st

environm

ent a

t ATS

• De

velop test plan an

d cond

uct testin

g at ATS

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d • Optim

ize call cen

ter staffing by de

veloping a re

al‐tim

e algorithm

that integrates with

and

im

proves upo

n existing call center staffin

g software to poten

tially predict variability in call

volume im

pacts in ne

ar re

al‐tim

e.

N/A

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d • De

velop a ne

w ra

te design tool th

at will ena

ble complex ra

te design such as for DER

ado

ption,

with

a m

ore robu

st, q

uicker and

pow

erful rate de

sign ap

proa

ch th

an th

e curren

t rate de

sign

process. Leveraging big da

ta te

chno

logies th

e tool will provide

rapid op

timiza

tion, ana

lysis and

evalua

tion of hypothe

tical new

rate structures which will ena

ble PG

&E an

d pa

rties in a rate case

to m

ake rate design de

cisio

ns based

on full inform

ation an

d nu

anced sensitivity ana

lysis

• • •

Desig

n an

d bu

ild cost o

f service datab

ase

Desig

n an

d bu

ild ra

te design mod

el engine an

d AP

IBu

ild fu

nctio

nality an

d ab

ility to

run DE

R scen

arios

*Date of award corrected from

previou

s ann

ual rep

ort

AppA-15

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th

e Project ‐ Deliverab

les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

• De

mon

strate autom

ated

and

remote control app

lication for g

eneric ene

rgy storage

resources to interface with

existing SCAD

A system

s.• Re

port fina

ncial perform

ance from

participation in CAISO

markets.

• Re

port com

parison

of a

ctua

l perform

ance vs. hypothe

tical perform

ance quo

ted in

indu

stry re

ports.

• Co

mply with

regulatory re

quire

men

ts and

estab

lish a fram

ework/recommen

datio

ns

for a

ccou

nting stan

dards a

pplicab

le to

ene

rgy storage.

2.75

years

9/19

/201

3No

Grid

Ope

ratio

n/Market

Desig

n

$ 616

,857

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

• Iden

tify en

ergy storage site ba

sed on

project objectiv

es.

• Iden

tify an econo

mic m

odeling tool to

com

pare th

e plan

ned trad

ition

al

alternatives usin

g distrib

uted

resources o

r dem

and‐sid

e investmen

ts.

• Co

nstruct a

nd integrate en

ergy storage system

.• Test sy

stem

and

ana

lyze re

sults to

prove project objectiv

es.

utility with

3.5 years

7/25

/201

4No

Distrib

ution; Grid

Ope

ratio

n/Market

Desig

n

$ 2,686

,621

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Grid

Ope

ratio

n/Market

Desig

n

$ 0

AppA-16

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Pilot F

acilitie

s for New

En


Rene

wab

les/DE

R Integration

Resource

N/A

N/A

NA

No

opGrid

erations/m

arket

desig

n N/A

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

source Forecast M

etho

ds

to Better P

redict Variable

Resource Outpu

t

Rene

wab

les/DE

R Integration

Resource

• Fully fu

nctio

nal m

esoscale m

odeling system

kno

wn as POMMS (PG&E Ope

ratio

nal

Mesoscale M

odeling System

) tha

t will provide

the following:

‐ Detailed weather inpu

t into PG

&E’s d

amage pred

ictio

n mod

eling system

(SOPP

).‐ N

ext g

eneration wildfire threat awaren

ess s

ystem.

‐ Historical and

forecast so

lar irrad

iance da

ta to

internal PG&E stakeh

olde

rs.

3.25

years

9/19

/201

3No

Distrib

ution

$ 535

,055

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Commun

ication System

s Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Rene

wab

les/DE

R Integration

Resource

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Grid

Ope

ratio

n/Market

Desig

n

$ 0

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

to Ram


d Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

NA

No

Grid

op

erations/m

arket

desig

n

N/A

AppA-17

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

System

Safety an

d Re

liability

through New

Data An

alytics

Techniqu

es

Grid

Mod

ernizatio

n Optim

izatio

nan

d • • • • • • • •

Overview of e

xisting ap

plications and

data sources.

Assessmen

t of e

xisting da

ta so

urce qua

lity.

High‐le

vel future bu

siness p

rocesses by functio

nal area.

Inventory of asset risk algorith

ms (form

ulas or com

plexity

) High‐le

vel Cha

nge Man

agem

ent A

pproach.

Prioritize

d an

d ph

ased

implem

entatio

n plan

.Co

st estim

ate for full implem

entatio

n of th

e STAR

project.

Proo

f of con

cept prototype

.

for “In Scope

” asset classes.

2.25

years

9/19

/201

3No

Tran

smiss

ion;

Distrib

ution

$ 1,249

,505

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for Existing

Tran

smiss

ion & Distrib

ution

Grid

Mod

ernizatio

n Optim

izatio

nan

d • A working prototype

for the

various Solid Blade

in Oil Ro

tatory Switch tools.

2.5 years

9/19

/201

3No

Tran

smiss

ion;

Distrib

ution

$ 301

,808

Assets: C

lose Proximity

Sw

itching

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Remote Mon

itorin

g an

d Co


Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Mod

ified

or improved

com

pone

nts ide

ntified

for u

se on Distrib

ution

Mon

itorin

g System

.• Im

proved

installatio

n an

d constructio

n work metho

ds.

• Econ

omic m

odel fo

r mainten

ance variables based

on life expe

ctan

cy

compo

nents.

• Ch

anges to compo

nents.

Network

testing of

3.25

years

9/19

/201

3No

Tran

smiss

ion;

Distrib

ution

$ 484

,250

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for T&D Assets:

Discrete Series R

eactors

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Installatio

n, te

sting an

d an

alysis of DSR and

server com

mun

ication links.

• Procure, con

struct and

test th

e DS

Rs.

• White pap

er describing project including go/no

go recommen

datio

n.• Fina

l rep

ort d

escribing overall project, including find

ing from

the op

erations

testing of DSR units and

a re

commen

datio

n as to

whe

ther or n

ot to

install the

elsewhe

re in th

e PG

&E system

.

and

DSRs

3.25

years

9/19

/201

3No

Tran

smiss

ion

$ 1,449

,835

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Tran

smiss

ion;

Distrib

ution

$ 0

Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

AppA-18

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

A

Prog

ram

Administrator

B

Project N

ame

C

Project T

ype

D

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

E3E4

FG

H I

For

Repo

rt

DOC

13 14 15 16 17

i. Investmen

t Plan Pe

riod

1st T

rienn

ial (20

12‐201

4)

1st T

rienn

ial (20

12‐201

4)

1st T

rienn

ial (20

12‐201

4)

1st T

rienn

ial (20

12‐201

4)

1st T

rienn

ial (20

12‐201

4)

PG&E

PG&E

PG&E

PG&E

PG&E

Project N

ame

1.10

C ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

1.11 ‐ De

mon

strate Self‐

Correctin

g To

ols to Im

prove

System

Records and

Ope

ratio

ns

1.12 ‐ De

mon

strate New

Techno

logies th

at Im

prove

Wildlife Safety and

Protect

Assets from

Weather‐

Related De

grad

ation

1.13 ‐ De

mon

strate New

Co

mmun

ication System

s to

Improve Substatio

n Au

tomation an

d Interope

rability

1.14 ‐ De

mon

strate "Next

Grid

Mod

ernizatio

n an

d Optim

izatio

n

Grid

Mod

ernizatio

n an

d Optim

izatio

n

Grid

Mod

ernizatio

n an

d Optim

izatio

n

Grid

Mod

ernizatio

n an

d Optim

izatio

n

Grid

Mod

ernizatio

n an

d

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Distrib

ution

$ 0

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Tran

smiss

ion;

Distrib

ution

$ 0

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Tran

smiss

ion;

Distrib

ution

$ 0

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Tran

smiss

ion;

Distrib

ution

$ 0

• Evalua

te new

app

lications and

devices, the

ir associated

data traffic im

pact on the

3.25

years

9/19

/201

3No

Distrib

ution;

$ 3,986

,281

Gen

eration" SmartM

eter™

Optim

izatio

nSm

artM

eter™ network, and

recommen

d which item

s warrant con

sideration for full scale

Grid

Telecom Network

deploymen

t.Ope

ratio

n/Market

181st T

rienn

ial (20

12‐201

4)PG

&E

Functio

nalities

1.15 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d

• De

velop bu

siness c

ase ba

sed on

find

ings fo

r full dep

loym

ent con

sideration.

Desig

n;

Deman

d‐Side

Man

agem

ent

• De

mon

strate Real‐tim

e Da

ta Visu

aliza

tion Platform

, including data integration from

a

3.25

years

9/19

/201

3No

Distrib

ution;

$ 1,334

,030

Techno

logies and

Strategies

Optim

izatio

nvarie

ty of d

ata sources a

nd a visu

al interface that includ

es geo

spatial, list, an

d tren

ding

Grid

Th

at Sup

port In

tegrated


Grid

" Ope

ratio

ns of the

Future

layers.

Ope

ratio

n/Market

Desig

n;De

man

d‐Side

Man

agem

ent

AppA-19

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Vehicle as a Resou

rce to

Improve Grid

Pow

er Qua

lity

and Re

duce Customer

Outages

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

velop op

erating requ

iremen

ts fo

r the

veh

icle.

• Und

erstan

d en

gine

ering challenges with

high po

wer export w

ith collabo

rativ

e supp

lier

developm

ent to solve.

• De

velop safety and

intercon

nection protocols to conn

ect the

veh

icle to

the grid

leveraging existing protocols for te

mpo

rary local gen

erator se

t con

nection.

• De

fine an

d do

cumen

t pow

er re

quire

men

ts fo

r differen

t outage/usage scen

arios.

• De

velop op

erating protocols (whe

n an

d ho

w th

e vehicles will be used

).• De

velop un

plan

ned ou

tage protocols.

• De

velop the ha

rdware an

d software (if re

quire

d) to

con

nect th

e vehicle to PG&E’s

system

.• Bu

ild veh

icles for field testing.

3.25

years

9/19

/201

3No

Distrib

ution

$ 1,688

,840

201st T

rienn

ial (20

12‐201

4)PG

&E



ulti‐

Utility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

Grid

Mod

ernizatio

n Optim

izatio

nan

d Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Tran

smiss

ion;

Distrib

ution

$ 0

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

SmartM

eter™‐ Ena

bled

Data


Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

Custom

er Service

Enab

lemen

tan

d • Qua

ntify disa

ggregatio

n accuracy and

com

pare ven

dors.

• Ba

sed on

results, p

rovide

recommen

datio

ns fo

r dep

loym

ent

level billing.

strategy of a

ppliance

2.5years

9/19

/201

3No

Deman

d‐Side

Man

agem

ent

$ 1,399

,248

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Techniqu

es and

Cap

abilitie

s via the Sm

artM

eter™

Platform

Custom

er Service

Enab

lemen

tan

d • Evalua

te new

data an

d an

alytic m

etho

dologies, the

ir associated

impa

ct on the

SmartM

eter™.

• Re

commen

datio

n of which data warrants c

onsid

eration for full‐scale dep

loym

ent.

• Evalua

tion shou

ld provide

key inpu

ts to

a business c

ase for g

eneral dep

loym

ent.

3.25

years

9/19

/201

3No

Distrib

ution;

Grid

Ope

ratio

n/Market

Desig

n;De

man

d‐Side

$ 1,054

,506

Man

agem

ent

AppA-20

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Be

nefits o

f Providing th

e Co

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er Service

Enab

lemen

tan

d N/A

N/A

NA

No

Deman

d‐Side

Man

agem

ent

N/A

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Au

tomatic Id

entification of

Distrib

uted

Ene

rgy Re

sources


hey

Intercon

nect to

the Grid

to

Custom

er Service

Enab

lemen

tan

d • Successful

system

.• Successful

• Successful integration of so

ftware with

PG&E’s C

ustomer Care

tracking of a

ll UIs iden

tified.

tracking of com

mun

ication an

d “con

version” of U

Is an

d Billing (C

C&B)

to intercon

nection.

2.5years

5/1/20

14No

Distrib

ution;

Deman

d‐Side

Man

agem

ent

$ 868

,495


251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate


ith

Subm

etering for E

Vs to


Flexibility

Custom

er Service

Enab

lemen

tan

d • Process to receive MDM

A subm

etered

data.

• Process to subtract EV da

ta from

prim

ary meter to

create tw

o bills.

• Inclusion of EV po

rtion of bill on custom

er’s m

onthly bill.

• Process for billing MDM

A for p

articipan

t sub

meter cha

rges.

• Obtain third

party evaluator fo

r both ph

ases of p

ilot throu

gh a Req

uest

(RFP).

• Incentive pa

ymen

ts to

MDM

A.

for P

ropo

sal

5years

11/14/20

13No

Distrib

ution;

Grid

Ope

ratio

n/Market

Desig

n;De

man

d‐Side

Man

agem

ent

$ 2,149

,416

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive

Billing W

ith Sub

metering for


Billing Flexibility

Custom

er Service

Enab

lemen

tan

d • Im

plem

ent p

ilot p

rogram

for d

edicated

smart m

eters a

nd th

ird party estim

ates.

• Explore op

portun

ities fo

r sub

metering techno

logy and

solar com

pany data exchan

ge.

• Mod

ify existing Cu

stom

er Data Wareh

ouse (C

DW)/MyEne

rgy interface to allow fo

r ad

ditio

nal data stream

s and

visu

aliza

tion.

• Evalua

te re

lativ

e merits of various gen

eration measuremen

t/estim

ation ap

proa

ches.

2.5 years

5/1/20

14No

Grid

Ops and

Mkt. D

esign /

Distrib

ution / D

SM

$ 950

,313

AppA-21

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Side

Man

agem

ent (DS

M) for

Tran

smiss

ion an

d

Custom

er Service

Enab

lemen

t and

• De

ploy data logging de

vices o

n a scientific sample of existing Sm

artAC™

Cycling

custom

ers, to

ena

ble real time mon

itorin

g of device pe

rforman

ce and

load im

pacts a

t feed

er level.

2 years

5/1/20

14No

Tran

smiss

ion;

Distrib

ution;

Grid

$ 1,196

,477

Distrib

ution (T&D) Cost

Redu

ction

• De

velop infrastructure to

make real‐tim

e da

ta available on

feed

er‐le

vel loa

d im

pacts

of SmartAC™

Cycling to distrib

ution op

erations.

• Prod

uce repo

rt describing a case stud

y metho

dology of targetin

g an

d valuing custom

e rsid

e pe

ak load re

ductions at the

feed

er level.

Ope

ratio

n/Market

Desig

n;De

man

d‐Side

Man

agem

ent

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map


ns fo

r DC

Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

Custom

er Service

Enab

lemen

t and

• De

velop a process to iden

tify op

timal DC fast

• De

velop a map th

at presents the

locatio

ns of

meaningful m

anne

r to custom

ers.

charging sites.

optim

al DC fast cha

rging sites in a

2.5 years

5/1/20

14No

Distrib

ution;

Deman

d‐Side

Man

agem

ent

$ 391

,425

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t an


nd

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d

Custom

er Service

Enab

lemen

t and

Project d

eliverab

les b

eing fu

rthe

r evaluated

‐ TB

DProject sched

ule

being furthe

r evalua

ted ‐ T

BD

NA

No

Grid

Ope

ratio

n/Market

Desig

n an

d De

man

d‐sid

e Man

agem

ent.

$ 0

Respon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage

the Distrib

ution Grid

on

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

NA

No

Grid

Ope

ratio

ns/M

arket

Desig

n;

Tran

smiss

ion;

Distrib

ution; DSM

$ 0

AppA-22

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

• Th

e functio

nal integratio

n of a DER

MS software minim

um viable prod

uct a

nd

operationa

l dem

onstratio

n of th

e iden

tified use cases.

• A repo

rt th

at:

‐ Determines th

e most impo

rtan

t cha

racteristics o

f a fu

ll de

ploymen

t solution includ

ing

detailed functio

nal and

technical req

uiremen

ts.

‐ Ide

ntifies best p

ractices and

requ

ired internal cap

abilitie

s for a fu

ll de

ploymen

t solutio

n.‐ D

evelop

s ope

ratio

nal processes th

at can be scaled

to a wider sy

stem

dep

loym

ent.

‐ Defines bou

ndaries a

nd integrations with

other PG&E system

s (e.g., D

RMS, DMS,

market systems).

‐ Develop

s a point of view on the utility ro

le in m

anaging DE

Rs fo

r grid

and

econo

mic

bene

fits.

2.75

years

9/15

/201

5No

Grid

Ope

ratio

n/Market

Desig

n

$ 2,444

,324

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

• Iden

tify feed

er(s) w

here Smart Inverters will be installed for d

emon

stratio

n.• De

mon

strate th

e use of Smart Inverters on on

e or m

ore feed

ers to de

mon

strate th

e inverters’ local voltage con

trol cap

abilitie

s and

impa

cts related

to high pe

netration of

custom

er sited solar P

V.• De

velop ne

cessary commun

ications so

ftware/ha

rdware/techno

logies between the

utility and

third

party aggregator o

r end

devices.

• Evalua

te th

e pe

rforman

ce of Smart Inverters to

supp

ort g

rid needs.

3.5years

4/10

/201

5No

Distrib

ution;

Deman

d‐Side

Man

agem

ent

$ 1,574

,148

AppA-23

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Vehicle to Hom

e

Rene

wab

les/DE

R Integration

Resource

• Evalua

tion of th

e pe

rforman

ce of the

EV

load during DR

and

hard islan

ding events.

• Co

st‐ben

efit evalua

tion

energy flow

cap

abilitie

s to supp

ort residen

tial

2years

1/8/20

16No

Distrib

ution;

Deman

d‐Side

Man

agem

ent

$ 225

,158

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g Vo

ltage Tracking

&

Rene

wab

les/DE

R Integration

Resource

• De

velop an ana

lytics p

rocess/algorith

m to

ana

lyze AMI

pene

tration DG

feed

ers, as w

ell as s

ome low pen

etratio

n • Evalua

te im

pact of D

G pen

etratio

n on

voltage.

and othe

r data for h

igh

feed

ers for baselining.

2years

4/10

/201

5No

Grid

Ope

ratio

ns/M

arket

Desig

n

$ 745

,762

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Emulation for D

G Im

pact

Improvem

ent

Rene

wab

les/DE

R Integration

Resource

• Evalua

tion of th

e po

wer sy

stem

’s need for reliability supp

ort, includ

ing iden

tifying

threshold cond

ition

s.• Assessmen

t of the

cap

abilitie

s of p

resent ene

rgy storage inverters for inertia

l freq

uency respon

se fu

nctio

ns.

• Provide recommen

datio

ns fo

r future inverter and

intercon

nection requ

iremen

ts to

provide inertia

l respo

nse.

2years

1/6/20

17No

Grid

Ope

ratio

ns/

Market D

esign;

Tran

smiss

ion

$ 244

,974

AppA-24

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

• De

velop a proo

f of con

cept th

at m

ay dem

onstrate:

1. an Intelligent Universal Transform

er (IUT) can be used

in lieu

conn

ect to Direct Current Fast C

harge (DCFC) protocols, and

2. an IUT can commun

icate ba

ck to

the utility.

of other equ

ipmen

t to

2.25

years

9/15

/201

5No

Distrib

ution;

Grid

Ope

ratio

n/Market

Desig

n;

Deman

d ‐Side

Man

agem

ent

$0

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

velop a

sources a

nd un

ique

load

ing

cade

nces.

algorithm

and

rubrics for determining cost effe

ctive da

ta3years

4/10

/201

5No

Grid

Ope

ratio

n/Market

Desig

n; Distrib

ution

$ 1,574

,317

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion

$0

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion

$0

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Co

mplete algorithm

s tha

t aggregate data from

multip

le

application.

• Incorporate multip

le algorith

ms into a proo

f of con

cept

• De

velop recommen

datio

n for d

eploym

ent strategy.

sources to feed

into

visualiza

tion tool.

3.5years

4/10

/201

5No

Tran

smiss

ion;

Distrib

ution

$ 2,425

,012

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Distrib

ution

$0

AppA-25

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Man

agem

ent M

obile

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion;

Distrib

ution

$ 0

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Substatio

n/Substatio

n Au

tomation

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion;

Distrib

ution

$ 0

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically

Phasing Inform

ationMap

Grid

Mod

ernizatio

n Optim

izatio

nan

d • De

velop algorithm

or n

ovel process to

use AMI d

ata an

d othe

r the assig

nmen

t of P

hases to cond

uctin

g compo

nents.

• Co

mplete an ana

lysis on the most cost‐effective freq

uency for

process.

sources

runn

ing

to determine

such a m

apping

2.5years

9/15

/201

5No

Distrib

ution;

Deman

d‐Side

Man

agem

ent

$ 1,566

,518

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Applications fo

r Gen

erator

Dyna

mic M

odel Validation

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Install synchroph

asors (or “PM

Us”) o

n gene

rators or g

enerator tie‐lines, and

de

mon

strate new

data an

alysis software ap

plications.

• Evalua

te th

e ap

plications’ ability to perform

gen

erator dynam

ic m

odel validation

analyzing synchrop

hasor d

ata following tran

sient disturba

nces on the tran

smiss

ion

system

.

by

3years

4/10

/201

5No

Tran

smiss

ion

$ 620

,157

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Synchrop

hasor A

nalytics

Applications

&

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion

$ 0

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Disturba

nce (GMD)

Evalua

tion

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion

$ 0

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Tran

sformers a

nd Sen

sors

Protectio

n an

d Co

ntrol

for Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DNA

No

Tran

smiss

ion

$ 0

System

s

AppA-26

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

Cu

stom

er Service and

• De

mon

strate and

test field results fo

r effe

ctiven

ess o

f the

use of a

ggregated custom

er‐

2.75

years

4/10

/201

5No

Distrib

ution;

$ 1,678

,045

De

man

d‐Side

Strategies &

En

ablemen

tsited

BTM

ene

rgy storage resources to pe

ak load re

duction an

d/or absorb distrib

uted

De

man

d‐Side

Techno

logies

gene

ratio

n on

a utility

distrib

ution feed

er(s).

Man

agem

ent

• Po

tential to de

mon

strate com

mun

ications with

aggregated resources for visu

aliza

tion

and control.

• Evalua

te cost‐effectiven

ess a

nd re

liability of BTM

ene

rgy storage for a

ddressing

capa

city con

straints.

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e En

ergy

Custom

er Service and

TB

DTB

DNA

No

Grid

Ope

ratio

ns/

$ 0

Usage Feedb

ack to

Enab

lemen

tMarket D

esign;

Custom

ers

Distrib

ution;

Deman

d‐Side

Man

agem

ent

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

Custom

er Service and

• Install Zigbe

e HA

N devices with

selected

LCI customers a

nd con

nect devices to

their

2.25

years

9/15

/201

5No

Deman

d‐Side

$ 8

,451

(HAN

) for Com

mercial

Enab

lemen

tSm

artM

eter™.

Man

agem

ent

Custom

ers

• Mon

itor customer usage and

issue/collect customer su

rveys.

• Co

mplete repo

rt with

iden

tified iss

ues a

nd re

commen

datio

ns fo

r how

to integrate

with

an existing EM

S.

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

Custom

er Service and

• Create a data an

alytics p

latform cap

able of com

bining and

ana

lyzin

g multi structured

2.5years

9/15

/201

5No

Distrib

ution;

$ 656

,887

through Targeted

Data

Enab

lemen

tda

ta, linking to

a variety of d

ata sources.

Deman

d‐Side

An

alytics

• De

velop a metho

d for ide

ntificatio

n, valua

tion, im

plem

entatio

n, and

tracking of

Man

agem

ent

targeted

DER

s.• Create a qua

ntita

tive screen

ing/rank order to

ol.

• De

velop actio

nable DE

R recommen

datio

ns to

customer outreach team

s for re

aching

deman

d redu

ction goals.

AppA-27

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Side

Customer Service and

• De

velop en

hanced

Customer and

DER

Loa

d Shap

es Catalog in PG&E's L

oadSEER

2.25

years

4/10

/201

5No

Distrib

ution;

$ 1,831

,735

Ap

proa

ches In

to Utility

En

ablemen

tPlan

ning Too

l.De

man

d‐Side

Plan

ning

• Incorporate DE

R Scen

ario Projections into Loa

dSEER.

Man

agem

ent

• De

velop interface be

tween Load

SEER

and

CYM

E for b

atch processing integration.

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Custom

er Service and

TB

DTB

DNA

No

Deman

d‐Side

$

0Disaggregatio

n for N

on‐

Enab

lemen

tMan

agem

ent

Resid

entia

l Customers

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart G

rid

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

NA

No

Grid

Ope

ratio

ns/

$0

Commun

ications

Market D

esign;

Distrib

ution;

Deman

d‐Side

Man

agem

ent

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Cross‐Cu

tting/Foun

datio

nal

• Co

nduct testin

g that will certify custom

er ope

n archite

cture de

vices/ap

plications th

at

2.75

years

9/15

/201

5No

Distrib

ution;

$ 1,113

,364

Distrib

ution Au

tomation

are AM

I com

patib

le, secure an

d interope

rable.

Grid

Ope

n Archite

cture De

vices

• Provide ph

ysical and

app

lication interfaces, as a

proof of con

cept, w

hich m

ay permit

Ope

ratio

n/Market

custom

er and

third

party devices to

con

nect to

our AMI n

etwork(s).

Desig

n;

Deman

d‐Side

Man

agem

ent

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Cross‐Cu

tting/Foun

datio

nal

• De

mon

strate an integrated

, multi‐tena

nt network man

agem

ent system th

at m

ay

3 years

4/10

/201

5No

Grid

$

576,43

3Integrated

Smart G

rid

includ

e the following features:

Ope

ratio

ns/M

arket

Network Man

agem

ent

‐ Integrated ne

twork man

agem

ent &

con

trol th

at will m

onito

r and

prio

ritize

data traffic.

Desig

n; Distrib

ution;

‐ Autom

ate trou

ble ticketin

g creatio

n process for workflow m

anagem

ent.

Deman

d‐Side

‐ A

sset m

anagem

ent o

f meter and

network eq

uipm

ent regardless o

f meter or n

etwork

Man

agem

ent

type

s.

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Cross‐Cu

tting/Foun

datio

nal

• Establish

the ba

se line

noise floo

r.1 year

1/6/20

17No

Grid

$

58,51

8Co

mmun

ications Path

• De

velop an

d de

mon

strate an ap

plication with

an algorithm

which can autom

atically

Ope

ratio

n/Market

Mon

itorin

gan

d continuo

usly iden

tify, m

onito

r, an

d confirm

RF interferen

ces for m

ultip

le sp

ectrum

s.De

sign

• Provide an end

‐end

process fo

r ide

ntifying, con

firming an

d mitigatin

g de

tected

interferen

ces w

ith th

e AM

I‐network.

AppA-28

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n of th

e Project ‐

Sche

dule (2

016)

Date of th

e Aw

ard

Was This P

roject

Awarde

d in th

e Im

med

iately Prio

r Ca

lend

ar Year?

Assign

men

t to

Utility

Value

Cha

inEn

cumbe

red

Fund

ing Am

ount

($)

AB

CD

E3E4

FG

H I

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

ii. Assignm

ent

Value Ch

ainto

viii. EPIC Fund

s En

cumbe

red

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile M

eter

Cross‐Cu

tting/Foun

datio

nal

• De

sign specificatio

n of m

obile m

eter.

3.5years

4/10

/201

5No

Grid

$ 984

,140

Applications

• De

mon

stratio

n of m

obile m

eter hardw

are prototype.

Ope

ratio

ns/M

arket

• En

d‐to‐end

meter to

cash testing using existing AM

I or cellular b

ased

network.

Desig

n; Distrib

ution;

• De

mon

stratio

n of use cases on DG

app

lications and

PEV

metering, includ

ing remote

Deman

d‐Side

an

d ne

ar re

al‐tim

e tracking of veh

icle cha

rge locatio

ns and

ene

rgy flo

w.

Man

agem

ent

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to Grid

Mod

ernizatio

n an

d TB

DTB

DNA

No

Grid

Ope

ratio

ns/

$ 0

Participate in In

dustry‐W

ide

Optim

izatio

nMarket D

esign;

RD&D Programs

Tran

smiss

ion;

Distrib

ution;

Deman

d‐Side

Man

agem

ent

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐

Rene

wab

les/DE

R Re

source

N/A

N/A

NA

N/A

Grid

N/A

The‐Meter Storage M

arket / Integration

Ope

ratio

ns/M

arket

Retail Optim

izatio

nDe

sign; Dem

and

Side

Man

agem

ent

AppA-29

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Project N

ame

Project T

ype

Brief D

escriptio

n of th


les

Brief D

escriptio

n Date of th

e Was This P

roject

Assign

men

t to

Encumbe

red

Administrator

of th

e Project ‐

Award

Awarde

d in th

e Utility

Value

Cha

inFund

ing Am

ount

Sche

dule (2

016)

Immed

iately Prio

r ($)

Calend

ar Year?

AB

CD

E3E4

FG

H I

For

ii. Assignm

ent to

viii. EPIC Fund

s Re

port

i. Investmen

t Plan Pe

riod

Project N

ame

v. Deliverab

les

vii. Sche

dule

Value Ch

ain

Encumbe

red

DOC

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric Loa

d Re

newab

les/DE

R Re

source

N/A

N/A

NA

N/A

Grid

N/A

Man

agem

ent for Ridesha

ring Integration

Ope

ratio

ns/M

arket

Electrificatio

nDe

sign; Distrib

ution;

Deman

d Side

Man

agem

ent

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service Issue

Grid

Mod

ernizatio

n an

d N/A

N/A

NA

N/A

Grid

N/A

Iden

tification Leveraging

Optim

izatio

nOpe

ratio

ns/M

arket

Mom

entary Outage

Desig

n; Distrib

ution

Inform

ation

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Grid

Mod

ernizatio

n an

d • Solutio

n archite

cture for integratin

g ad

ditio

nal sen

sor techn

ology into line

sensors.

1year

8/10

/201

7Yes

Grid

$

0Iden

tification with

Rad

io

Optim

izatio

nOpe

ratio

ns/M

arket

Freq

uency (RF) Add

ed to

Line

Desig

n; Distrib

ution

Sensors

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter Staffing

Grid

Mod

ernizatio

n an

d N/A

N/A

NA

N/A

Grid

N/A

Optim

izatio

nOptim

izatio

nOpe

ratio

ns/M

arket

Desig

n

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐ Dy

namic Rate De

sign

Custom

er Service and

• Technical architecture specificatio

ns1.25

years

8/10

/201

7Yes

Grid

$

0To

olEn

ablemen

t• Da

ta m

odel and

datab

ases

Ope

ratio

ns/M

arket

• Ra

te design mod

el engine an

d AP

IDe

sign; Dem

and

Side

Man

agem

ent


previou

s ann

ual rep

ort

AppA-30

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

$1,66

0,00

0 ‐ $

2,03

0,00

0 $ 778

,040

$ 1,05

5,92

8$ 1,83

3,96

8All project costs

are related to

project a

ctivities.

Admin costs are

tracked

sepa

rately.

Leveraged ba

ttery assets th

at

was fu

nded

by En

ergy Regulators

Region

al Associatio

n (ERR

A).

Leveraged $1

63K, as w

ell as

software an

d expe

rtise

from

PG

&E's h

ydro gen

eration grou

p.

N/A

N/A

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

$3,61

0,00

0 ‐ $

4,41

2,00

0$ 2,75

7,65

0$ 1,25

2,86

0$ 4,01

0,51

0All project costs

are related to

project a

ctivities.

Admin costs are

tracked

sepa

rately.

No

N/A

No

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

$ 0

$ 0

$ 0

$ 0

$ 0

TBD

TBD

TBD

Q

AppA-31

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Pilot F

acilitie

s for New

En


Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

source Forecast M

etho

ds

to Better P

redict Variable

Resource Outpu

t

Rene

wab

les/DE

R Integration

Resource

$72

0,00

0 ‐ $

880,00

0

$ 511

,681

$ 31

2,20

9

$ 82

3,89

0

All project costs

are related to

project a

ctivities.

Admin costs are

tracked

N/A

N/A

N/A

sepa

rately.

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Commun

ication System

s Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Rene

wab

les/DE

R Integration

Resource

$ 0

$

0$

0$

0$ 0

N/A

N/A

N/A

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

to Ram


d Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

Q

AppA-32

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

System

Safety an

d Re

liability

through New

Data An

alytics

Techniqu

es

Grid

Mod

ernizatio

n Optim

izatio

nan

d $1,90

0,00

0 ‐ $

2,32

0,00

0 $ 1,79

1,80

5$ 32

0,83

5

$ 2,11

2,64

0All project costs

are related to

project a

ctivities.

Admin costs are

tracked

N/A

N/A

N/A

sepa

rately.

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for Existing

Tran

smiss

ion & Distrib

ution

Grid

Mod

ernizatio

n Optim

izatio

nan

d $46

4,00

0 ‐ $

567,00

0 $ 382

,094

$ 13

3,17

4

$ 51

5,26

8

All project costs

are related to

project a

ctivities.

Admin costs are

N/A

N/A

N/A

Assets: C

lose Proximity

Sw

itching

tracked

sepa

rately.

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Remote Mon

itorin

g an

d Co


Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

Grid

Mod

ernizatio

n Optim

izatio

nan

d $45

0,00

0 ‐ $

550,00

0

$ 543

,414

$ 4,267

$ 54

7,75

3

All project costs

are related to

project a

ctivities.

Admin costs are

tracked

sepa

rately.

N/A

N/A

N/A

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for T&D Assets:

Discrete Series R

eactors

Grid

Mod

ernizatio

n Optim

izatio

nan

d $2,21

00,000 ‐

$2,710

,000

$ 1,54

5,89

5$ 91

3,83

8

$ 2,44

0,93

0All project costs

are related to

project a

ctivities.

Admin costs are

N/A

N/A

N/A

tracked

sepa

rately.

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

Q

AppA-33

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d $

0$ 0

$ 0$ 0

TBD

TBD

TBD

TBD

Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Correctin

g To

ols to Im

prove

System

Records and

Ope

ratio

ns

Grid

Mod

ernizatio

n Optim

izatio

nan

d $

0$ 0

$ 0$ 0

TBD

TBD

TBD

TBD

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Techno

logies th

at Im

prove

Wildlife Safety and

Protect

Assets from

Weather‐

Grid

Mod

ernizatio

n Optim

izatio

nan

d $

0$ 0

$ 0$ 0

TBD

TBD

TBD

TBD

Related De

grad

ation

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Co

mmun

ication System

s Im

prove Substatio

n Au

tomation an

d

to

Grid

Mod

ernizatio

n Optim

izatio

nan

d $

0$ 0

$ 0$ 0

TBD

TBD

TBD

TBD

Interope

rability

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Gen

eration" SmartM

eter™

Telecom Network

Functio

nalities

Grid

Mod

ernizatio

n Optim

izatio

nan

d $3,78

0,00

0 ‐ $

4,55

0,00

0 $ 3,32

1,00

5$ 81

2,42

2

$ 4,13

3,42

6All project costs

are related to

project a

ctivities.

Admin costs are

No

N/A

N/A

tracked

sepa

rately.

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Techno

logies and

Strategies

That Sup

port In

tegrated


Grid

Mod

ernizatio

n Optim

izatio

nan

d $3,78

0,00

0$4

,620

,000 ‐

$ 1,59

2,30

2$ 2,54

0,87

1$ 4,13

3,17

3$

0N/A

N/A

N/A

Grid

" Ope

ratio

ns of the

Future

Q

AppA-34

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PQ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Vehicle as a Resou

rce to

Improve Grid

Pow

er Qua

lity

and Re

duce Customer

Outages

Grid

Mod

ernizatio

n Optim

izatio

nan

d $3,60

0,00

0 ‐ $

4,40

0,00

0 $ 2,44

8,16

5$ 1,56

1,62

2$ 4,00

9,78

8$ 125

Depa

rtmen

t of E

nergy (DOE)

provided

test se

rvices usin

g Nationa

l Ren

ewab

le Ene

rgy Lab

(NRE

L) fa

cilities. A

pproximate

cost sh

are to date: $12

0,00

0.

DOE/NRE

L; Edison Electric

Institu

te engaged

for e

lec.

utility indu

stry staging even

ts;

Portland

Gen

eral Electric closely

collabo

ratin

g for ind

ustry‐level

requ

iremen

ts

N/A

201st T

rienn

ial (20

12‐201

4)PG

&E



ulti‐

Utility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0$ 0

TBD

TBD

N/A

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

SmartM

eter™‐Ena

bled

Data

Custom

er Service

Enab

lemen

tan

d $1,08

0,00

0 ‐ $

1,32

0,00

0$ 1,23

1,13

1$ 6

5,71

1

$ 1,29

6,84

2All project costs

are related to

N/A

N/A

N/A


Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

project a

ctivities.

Admin costs are

tracked

sepa

rately.

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Techniqu

es and

Cap

abilitie

s via the Sm

artM

eter™

Platform

Custom

er Service

Enab

lemen

tan

d $1,78

0,00

0 ‐ $

2,18

0,00

0 $ 831

,015

$ 1,14

9,48

4$ 1,98

0,49

9All project costs

are related to

project a

ctivities.

Admin costs are

Leveraging existing

investmen

ts.

AMI n

etwork

N/A

N/A

tracked

sepa

rately.

AppA-35

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Be

nefits o

f Providing th

e Co

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Au

tomatic Id

entification of

Custom

er Service

Enab

lemen

tan

d $1,20

0,00

0 ‐ $

1,46

0,00

0 $ 890

,314

$ 43

7,46

7

$ 1,32

7,78

2All project costs

are related to

N/A

N/A

N/A

Distrib

uted

Ene

rgy Re

sources


hey

Intercon

nect to

the Grid

to

project a

ctivities.

Admin costs are

tracked


sepa

rately.

251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate


ith

Subm

etering for E

Vs to


Flexibility

Custom

er Service

Enab

lemen

tan

d $1,73

0,00

0 ‐ $

2,12

0,00

0 $ 1,59

8,49

8$ 32

5,62

9

$ 1,92

4,12

8All project costs

are related to

project a

ctivities.

Admin costs are

tracked

sepa

rately.

N/A

N/A

N/A

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive

Billing W

ith Sub

metering for


Billing Flexibility

Custom

er Service

Enab

lemen

tan

d $1,20

0,00

0 ‐ $

1,46

0,00

0 $ 872

,927

$ 45

0,89

0

$ 1,32

3,81

7All project costs

are related to

project a

ctivities.

Admin costs are

tracked

N/A

N/A

N/A

sepa

rately.

Q

AppA-36

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Amou

nt ($)

to Date:

Contract/G

rant

Amou

nt ($

)

to Date: In

Hou

se

Expe

nditu

res ($)

to Date: Total

Spen

t to Date ($

)an

d Overhead

Costs to Be

Incurred

for E

ach

Project

J K

L

M

NO

P

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Side

Man

agem

ent (DS

M) for

Tran

smiss

ion an

d Distrib

ution (T&D) Cost

Redu

ction

Custom

er Service

Enab

lemen

tan

d $1,32

7,00

0 ‐ $

1,62

1,00

0 $ 1,26

2,77

0$ 7

7,58

3

$ 1,34

0,35

3All project costs

are related to

project a

ctivities.

Admin costs are

tracked

N/A

N/A

N/A

sepa

rately.

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map


ns fo

r Cu

stom

er Service

Enab

lemen

t and

$40

0,00

0 ‐ $

490,00

0 $ 311

,851

$ 13

2,61

8

$ 44

4,46

9

All project costs

are related to

N/A

N/A

N/A

DC Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

project a

ctivities.

Admin costs are

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

tracked

sepa

rately.

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t an


nd

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d

Custom

er Service

Enab

lemen

t and

$

0$ 0

$ 0$ 0

TBD

TBD

TBD

TBD

Respon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage

the Distrib

ution Grid

on

Rene

wab

les/DE

R Integration

Resource

$0

$ 0$ 0

$ 0TB

DTB

DTB

DTB

D

AppA-37

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

AB

CD

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

J K

L

M

NO

PQ

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

$6,00

0,00

0 ‐ $

7,32

0,00

0 $ 2,66

5,14

8$ 3,06

5,66

1$ 5,73

0,80

9 $ 8,878 N/A

N/A

$419

,000

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

$4,767

,300 ‐ $5,82

6,70

0$ 1,19

3,60

9$ 1,02

1,73

7$ 2,21

5,34

6$1

,140

This project is leveraging fund

s from

the PG

&E Smart G

rid

Volt/Va

r Optim

izatio

n (VVO

) pilot g

iven

they are com

pleting

the testing of th

e functio

nality of

the sm

art inverter techn

ologies.

The results of the

testing will

impa

ct th

is project's opp

ortunity

to laun

ch.

N/A

TBD

Q

AppA-38

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Project N

ame

Project T

ype

Committed

Fun

ding

Fund

s Expen

ded

Fund

s Expen

ded

Fund

s Expen

ded

Administrative

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

Administrator

Amou

nt ($)

to Date:

to Date: In

Hou

se

to Date: Total

and Overhead

Contract/G

rant

Expe

nditu

res ($)Sp

ent to Date ($

)Co

sts to Be

Am

ount ($

)Incurred

for E

ach

Project

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Rene

wab

les/DE

R Re

source

$414

,000 ‐ $5

06,000

$ 192

,117

$ 26

7,53

4

$ 45

9,65

1

$11

,224 T

BDTB

DTB

DEn

hanced

Cap

abilitie

s ‐

Integration

Vehicle to Hom

e

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g &

Rene

wab

les/DE

R Re

source

$1,11

0,00

0 ‐ $

1,36

0,00

0 $ 816

,364

$ 41

6,92

9

$ 1,23

3,29

3 $

7,58

3 TB

DTB

DTB

DVo

ltage Tracking

Integration

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Rene

wab

les/DE

R Re

source

$1,45

0,00

0 ‐ $

1,78

0,00

0 $ 58

,939

$ 4

3,96

7

$ 10

2,90

6

TBD

TBD

Nationa

l Ren

ewab

le Ene

rgy

N/A

Emulation for D

G Im

pact

Integration

Labo

ratory se

lected

as testin

g Im

provem

ent

and de

mon

stratio

n provider.

Q

AppA-39

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

$ 0

$

0$

0$

0$ 0

N/A

N/A

N/A

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d $2,42

0,00

0 ‐ $

2,95

8,00

0 $ 1,30

0,09

9$ 74

6,30

5

$ 2,04

6,40

3 $ 10,59

2 TB

DTB

DTB

D

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d $3,99

3,00

0$4

,881

,000

‐

$ 2,47

7,19

0$ 59

9,90

2

$ 3,07

7,09

2 $ 1,538 TBD

TBD

TBD

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

Q

AppA-40

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Man

agem

ent M

obile

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Substatio

n/Substatio

n Au

tomation

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically

Phasing Inform

ationMap

Grid

Mod

ernizatio

n Optim

izatio

nan

d $1,66

0,00

0 ‐ $

2,03

0,00

0 $ 1,52

8,64

5$ 17

2,74

8

$ 1,70

1,39

4 $ 11,64

8 TB

DPG

&E is working with

University

of Califo

rnia, R

iversid

e to te

st

an alte

rnate algorithm

based

ap

proa

ch which will be

evalua

ted against o

ther

solutio

ns dem

onstrated in

TBD

project

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Applications fo

r Gen

erator

Dyna

mic M

odel Validation

Grid

Mod

ernizatio

n Optim

izatio

nan

d $65

4,00

0 ‐ $

799,00

0 $ 545

,293

$ 18

1,14

2

$ 72

6,43

5

$ 800 TBD

TBD

TBD

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Synchrop

hasor A

nalytics

Applications

&

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Disturba

nce (GMD)

Evalua

tion

Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Tran

sformers a

nd Sen

sors

Protectio

n an

d Co

ntrol

for Grid

Mod

ernizatio

n Optim

izatio

nan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

System

s

Q

AppA-41

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

De

man

d‐Side

Strategies &

Techno

logies

Custom

er Service

Enab

lemen

tan

d $2,61

5,00

0 ‐

$3,197

,000

$ 1,32

2,06

0$ 61

6,23

3

$ 1,93

8,29

2 $ 24,68

6 TB

DTB

DTB

D

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e Usage Feedb

ack

Custom

ers

Energy

to

Custom

er Service

Enab

lemen

tan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

(HAN

) for Com

mercial

Custom

ers

Custom

er Service

Enab

lemen

tan

d $18

0,00

0 ‐ $

220,00

0 $ 12

,302

$ 20

1,17

4

$ 21

3,47

6

$ 3,193 TBD

Rainforest Autom

ation

providing de

velopm

ent o

f the

clou

d service ap

plication used

by th

e custom

ers

TBD

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

through Targeted

Data

Analytics

Custom

er Service

Enab

lemen

tan

d $1,73

4,00

0 ‐

$2,120

,000

$ 731

,667

$ 60

2,36

3

$ 1,33

4,02

9 $ 13,02

1 TB

DTB

DN/A

Q

AppA-42

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Ap

proa

ches In

to Utility

Plan

ning

Side

Customer Service

Enab

lemen

tan

d $2,83

1,00

0 ‐

$3,461

,000

$ 1,81

2,99

1$ 1,26

1,76

4$ 3,07

4,75

5 $ 8,188 TBD

TBD

TBD

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Disaggregatio

n for N

on‐

Resid

entia

l Customers

Custom

er Service

Enab

lemen

tan

d $ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart

Commun

ications

Grid

Cross‐Cu

tting/Foun

datio

nal

$ 0

$

0$

0$

0TB

DTB

DTB

DTB

D

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Distrib

ution Au

tomation

Ope

n Archite

cture De

v ices

Cross‐Cu

tting/Foun

datio

nal

$3,01

5,00

0$3

,685

,000 ‐

$ 68

,481

$ 1,07

5,19

3$ 1,14

3,67

5 $ 49,13

3 TB

DTB

DTB

D

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Integrated

Smart G

rid

Network Man

agem

ent

Cross‐Cu

tting/Foun

datio

nal

$1,00

8,00

0$1

,232

,000 ‐

$ 545

,754

$ 56

4,20

8

$ 1,10

9,96

2 $ 6,363 TBD

TBD

TBD

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Commun

ications

Mon

itorin

gPath

Cross‐Cu

tting/Foun

datio

nal

$22

7,00

0 ‐ $

277,00

0 $ 63

,687

$ 18

8,18

2

$ 25

1,86

9

TBD

TB

DTB

DTB

D

Q

AppA-43

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Project N

ame

Project T

ype

Committed

Fun

ding

Fund

s Expen

ded

Fund

s Expen

ded

Fund

s Expen

ded

Administrative

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

Administrator

Amou

nt ($)

to Date:

to Date: In

Hou

se

to Date: Total

and Overhead

Contract/G

rant

Expe

nditu

res ($)Sp

ent to Date ($

)Co

sts to Be

Am

ount ($

)Incurred

for E

ach

Project

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile M

eter

Cross‐Cu

tting/Foun

datio

nal

$2,61

0,00

0 ‐

$ 1,07

6,77

3$ 51

5,55

3

$ 1,59

2,32

6 $

30,130 In‐kind

services fo

r resou

rce tim

e Lawrence Liverm

ore Nationa

l TB

DAp

plications

$3,190

,000

from

Law

rence Liverm

ore

Lab providing technical sup

port

Nationa

l Lab (LLN

L) on technical

for p

rodu

ct develop

men

t specificatio

n calls

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to Grid

Mod

ernizatio

n an

d $

0$

$$

TBD

TBD

TBD

TBD

Participate in In

dustry‐W

ide

Optim

izatio

n0

00

RD&D Programs

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐

Rene

wab

les/DE

R Re

source

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A


arket / Integration

Retail Optim

izatio

n

Q

AppA-44

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Committed

Fun

ding

Amou

nt ($)

Fund

s Expen

ded

to Date:

Contract/G

rant

Amou

nt ($

)

Fund

s Expen

ded

to Date: In

Hou

se

Expe

nditu

res ($)

Fund

s Expen

ded

to Date: Total

Spen

t to Date ($

)

Administrative

and Overhead

Costs to Be

Incurred

for E

ach

Project

Leveraged Fund

sPa

rtne

rs

Match Fun

ding

AB

CD

J K

L

M

NO

PFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

ix. EPIC Fund

s Sp

ent

x. Partners (if ap

plicab

le)

xi. M

atch Fun

ding

(if app

licab

le)

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service

Iden

tification

Mom

entary O

Inform

ation

Issue

Leveraging

utage

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d $1,65

5,00

0 ‐

$2,023

,000

$

0$

0$

0TB

DTB

DTB

D

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

N/A

N/A

N/A

N/A

N/A

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d $1,91

3,00

0 ‐

$2,338

,000

$

0$

0$

0TB

DTB

DTB

D


previou

s ann

ual rep

ort

Q

AppA-45

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

N/A

Pay for

performan

ceN/A

Sole Sou

rce:

•Pow

er Settle

men

ts Con

sulting (sole vend

or th

atcould provide solutio

n with

out m

odificatio

n or

requ

ired ha

rdware).

• Trim

ark Associates (e

nhan

cemen

ts were mad

e to

their e

quipmen

t for th

is EP

IC project, as the

y were

the original ven

dor u

nder th

e capital project fo

r the

Yerba Bu

ena an

d Va

ca batterie

s).

N/A

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

N/A

Pay for

Performan

ceN/A

Compe

titive Bid

11

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

TBD

TBD

TBD

V

AppA-46

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Re

newab

les/DE

R Re

source

N/A

N/A

N/A

N/A

N/A

Pilot F

acilitie

s for New

Integration

Energy Storage Systems.

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

newab

les/DE

R Re

source

N/A

Pay for

N/A

Compe

titive Bid & Sole Source

• 1st a

ward: 6

Resource Forecast M

etho

ds Integration

performan

ce• 1st a

ward to create raw, grid

ded weather fo

recast• 2n

d aw

ard: 6

to Better P

redict Variable

data: com

petitive.

Resource Outpu

t• 2n

d aw

ard to develop

map of variables from

data:

completive.

• 3rd aw

ard: Sole source to

Clean Pow

er Research

due to obtain PV

estim

ation for inclusio

n in so

lar

irrad

iance use case.

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Rene

wab

les/DE

R Re

source

N/A

N/A

N/A

TBD

TBD

Commun

ication System

s Integration

Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

Rene

wab

les/DE

R Re

source

N/A

N/A

N/A

N/A

N/A

to Ram


d Integration

Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

V

AppA-47

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

Grid

Mod

ernizatio

n an

d N/A

Pay for

N/A

Compe

titive Bid

• 11

total bidde

rsSystem

Safety an

d Re

liability

Optim

izatio

npe

rforman

ce• 7 pa

ssed

initial sc

reen

through New

Data An

alytics

Techniqu

es

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Grid

Mod

ernizatio

n an

d N/A

Pay for

N/A

Compe

titive Bid

4Mon

itorin

g an

d Co

ntrol

Optim

izatio

nPe

rforman

ceSystem

s for Existing

Tran

smiss

ion & Distrib

ution

Assets: C

lose Proximity

Sw

itching

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Grid

Mod

ernizatio

n an

d N/A

Pay for

N/A

Compe

titive Bid

Phase I: 5 bids

Remote Mon

itorin

g an

d Optim

izatio

npe

rforman

cePh

ase 2: 8 bids

Control Systems for T&D

Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Grid

Mod

ernizatio

n an

d N/A

Pay for

N/A

Sole Sou

rce ‐ Smart W

ires, In

c. se

lected

as the

y are

N/A

Mon

itorin

g an

d Co

ntrol

Optim

izatio

nPe

rforman

cethe de

velope

r and

sole su

pplier o

f DSR devices.

System

s for T&D Assets:

Discrete Series R

eactors

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DAu

tomated

Asset

Optim

izatio

nNotificatio

n an

d Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

V

AppA-48

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv.Treatm

ent o

fIntellectua

l Prope

rty

applicab

le)

(if

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DAu

tomated

Asset

Optim

izatio

nNotificatio

n an

d Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DCo

rrectin

g To

ols to Im

prove

Optim

izatio

nSystem

Records and

Ope

ratio

ns

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DTechno

logies th

at Im

prove

Optim

izatio

nWildlife Safety and

Protect

Assets from

Weather‐

Related De

grad

ation

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DCo

mmun

ication System

s to

Optim

izatio

nIm

prove Substatio

n Au

tomation an

d Interope

rability

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Grid

Mod

ernizatio

n an

d N/A

Pay for

Patents filed for ‐

Sole Sou

rce ‐ Silver Springs Network selected

as

N/A

Gen

eration" SmartM

eter™

Optim

izatio

nPe

rforman

ce1)

Smart P

ole Meter,

they so

lutio

ns provide

r for PG&E’s A

MI electric

Telecom Network

2) Smart P

ole Meter

netw

ork. It is necessary to

work with

SSN

to ensure

Functio

nalities

Socket and

that devices and

app

lications can com

mun

icate

3) An algorithm

to help

across th

e AM

I network.

iden

tify do

wne

d wire

s

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d N/A

Pay For

New

Intellectua

l Prope

rty Co

mpe

titive Bid

3Techno

logies and

Strategies

Optim

izatio

nPe

rforman

ce(IP

) has been created

That Sup

port In

tegrated

through co‐develop

men

t "Customer‐to‐Market‐to‐

with

the vend

or. PG&E

Grid

" Ope

ratio

ns of the

retains o

wne

rship rig

hts

Future

to th

e IP and

will provide

free unlim

ited use rig

hts

to CA IOUs p

er th

e CP

UC

decisio

n

V

AppA-49

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv.Treatm

ent o

fIntellectua

l Prope

rty

applicab

le)

(if

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Grid

Mod

ernizatio

n an

d N/A

Pay for

N/A

• Ph

ase 1 (M

ule Ph

ase): 2 Dire

ct Awards ‐ Efficient

2 (Pha

se 3 ‐ Be

ta Pha

se)

Vehicle as a Resou

rce to

Optim

izatio

npe

rforman

ceDrivetrains, In

c. (E

DI) a

nd Electric Veh

icle

Improve Grid

Pow

er Qua

lity

Internationa

l (EV

I) selected

due

to sh

ort‐term

an

d Re

duce Customer

availability of prototype

driv

eline an

d capa

bility of

Outages

gene

ratin

g utility‐grade

export p

ower on F550

‐ diesel/gasoline configuration

• Ph

ase 2 (Alpha Pha

se): Ba

sed on

results of M

ule

phase, m

oved

forw

ard with

EDI, w

hich was

desig

ned to help form

ulate specs for Pha

se 3

• Ph

ase 3 (Beta Ph

ase): C

ompe

titive solicita

tion. 10

potential bidde

rs. R

eceived 2 fin

al bids.

201st T

rienn

ial (20

12‐201

4)PG

&E


s Grid

Mod

ernizatio

n an

d N/A

TBD

TBD

TBD

TBD

by Participating in M

ulti‐

Optim

izatio

nUtility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

Custom

er Service and

N/A

Pay for

N/A

Sole Sou

rce ‐ Silver Springs Network, as the

y are

N/A

SmartM

eter™‐Ena

bled

Data

Enab

lemen

tpe

rforman

cethe solutio

ns provide

r for PG&E’s A

MI electric


netw

ork. It is necessary to

work with

SSN

to ensure

Custom

ers W

ith App

liance‐

that devices and

app

lications can com

mun

icate

Level Ene

rgy Use In

form

ation

across th

e AM

I network.

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Custom

er Service and

N/A

Pay for

N/A

Compe

titive Bid

3Techniqu

es and

Cap

abilitie

s En

ablemen

tPe

rforman

cevia the Sm

artM

eter™

Platform

V

AppA-50

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv.Treatm

ent o

fIntellectua

l Prope

rty

applicab

le)

(if

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Cu

stom

er Service and

N/A

N/A

N/A

N/A

N/A

Bene

fits o

f Providing th

e En

ablemen

tCo

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Cu

stom

er Service and

N/A

Pay for

Patent filed for a

n Sole Sou

rce ‐ N

exan

t selected du

e to expertise in

N/A

Automatic Id

entification of

Enab

lemen

tpe

rforman

cealgorithm

which can

PG&E's C

C&B da

taba

se, PV gene

ratio

n da

ta ana

lysis

Distrib

uted

Ene

rgy Re

sources

detect una

utho

rized

PV

and AM

I network.


hey

Intercon

nections

Intercon

nect to

the Grid

to


251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate

Custom

er Service and

N/A

Pay for

N/A

Compe

titive Bid

15Subtractive Billing W

ith

Enab

lemen

tPe

rforman

ceSubm

etering for E

Vs to


Flexibility

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive Cu

stom

er Service and

N/A

Pay for

N/A

• Sole Sou

rce ‐

N/A

Billing W

ith Sub

metering for

Enab

lemen

tpe

rforman

ce‐ O

power ‐ PG

&E's c

ustomer fa

cing web

portal, My


Energy. G

iven

the project is integrated PV

Billing Flexibility

gene

ratio

n interval data into M

y En

ergy, it w

as

necessary to work with

them

.‐ C

lean Pow

er Research ‐ P

urchased

subscriptio

n to

estim

ated

gen

eration da

ta.

V

AppA-51

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Custom

er Service and

N/A

Pay for

N/A

Sole so

urced ‐ E

netics is a

con

sulting firm

that

N/A

Side

Man

agem

ent (DS

M) for En

ablemen

tpe

rforman

cepe

rformed

a stud

y that assessed the available

Tran

smiss

ion an

d techno

logies th

at wou

ld best a

ddress th

e ne

ed of

Distrib

ution (T&D) Cost

the project a

nd determined

Ene

tics p

rovide

s tha

t Re

duction

solutio

n. The

y were also willing to m

ake

enha

ncem

ents to

their d

evice to fu

rthe

r meet the

ne

ed of P

G&E an

d were the lowest cost a

nd

immed

iately available.

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map C

ustomer Service and

N/A

Pay for

N/A

Compe

titive Bid

4Th

e Preferred Locatio

ns fo

r En

ablemen

tPe

rforman

ceDC

Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t Cu

stom

er Service and

TB

DTB

DTB

DTB

DTB

Dan


nd Ena

blem

ent

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d Re

spon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage on

Rene

wab

les/DE

R Re

source

TBD

TBD

TBD

TBD

TBD

the Distrib

ution Grid

Integration

V

AppA-52

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

N/A

Pay for

performan

ceTB

DCo

mpe

titive Bid

5

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

TBD

Pay for

Performan

ceN/A

Sole Sou

rce ‐ SolarCity se

lected

due

to th

eir large

resid

entia

l market sha

re and

large am

ount of

custom

ers o

n im

pacted

distrib

ution circuits th

at is

most relevan

t to test th

eir techn

ologies.

TBD

V

AppA-53

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Vehicle to Hom

e

Rene

wab

les/DE

R Integration

Resource

TBD

Pay for

Performan

ceN/A ‐ No curren

t evide

nce

of In

tellectua

l Prope

rty

developm

ent

Quick Bid

4

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g Vo

ltage Tracking

&

Rene

wab

les/DE

R Integration

Resource

TBD

Pay for

Performan

ceN/A

Compe

titive Bid

12

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Emulation for D

G Im

pact

Improvem

ent

Rene

wab

les/DE

R Integration

Resource

N/A

Pay for

performan

ceN/A

Quick Bid

4

V

AppA-54

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv.Treatm

ent o

fIntellectua

l Prope

rty

applicab

le)

(if

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DPay for

Performan

ceN/A

Compe

titive Bid

12

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DTB

DTB

D

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DTB

DTB

D

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DPay for

Performan

cePG

&E will re

ceive

perpetua

l, tran

sferab

le

sublicen

ses to all W

ork

Prod

uct to use for current

and future PG&E

busin

ess.

Compe

titive Bid

3

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DTB

DTB

D

V

AppA-55

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DMan

agem

ent M

obile

Optim

izatio

nAp

plications

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DSubstatio

n/Substatio

n Optim

izatio

nAu

tomation

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically M

ap

Grid

Mod

ernizatio

n an

d TB

DPay for

N/A

• Sole Sou

rce ‐

TBD

Phasing Inform

ation

Optim

izatio

npe

rforman

ce‐ Silver Springs Network selected

as the

y are the

solutio

ns provide

r for PG&E’s A

MI electric network.

It is ne

cessary to work with

SSN

to ensure that

devices a

nd app

lications can com

mun

icate across

the AM

I network.

‐ Navigan

t selected du

e to indu

stry expertise an

d familiarity

with

PG&E‐specific system

s‐ C

onsulting branch of UC Riverside selected

per

indu

stry expertise

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Grid

Mod

ernizatio

n an

d TB

DPay for

N/A

• Sole Sou

rce ‐

N/A

Applications fo

r Gen

erator

Optim

izatio

npe

rforman

ce‐ M

athW

orks was se

lected

as the

software tool

Dyna

mic M

odel Validation

because they are th

e on

ly com

mercial ven

dor o

f this type

of p

aram

eter estim

ation tool re

quire

d for

the project.

‐ Schweitzer Engineerin

g Labs was se

lected

as the

PM

U ven

dor b

ecau

se th

ey are th

e on

ly ven

dor to

offer a

mod

ule to m

easure gen

erator ro

tor a

ngle

which was necessary fo

r the

mod

eling effort.

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DSynchrop

hasor A

nalytics &

Optim

izatio

nAp

plications

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DDisturba

nce (GMD)

Optim

izatio

nEvalua

tion

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Grid

Mod

ernizatio

n an

d TB

DTB

DTB

DTB

DTB

DTran

sformers a

nd Sen

sors fo

r Optim

izatio

nProtectio

n an

d Co

ntrol

System

s

V

AppA-56

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

VFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

De

man

d‐Side

Strategies &

Techno

logies

Custom

er Service

Enab

lemen

tan

d TB

DPay for

Performan

ceN/A ‐ No curren

t evide

nce

of In

tellectua

l Prope

rty

developm

ent

Compe

titive Bid

10

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e Usage Feedb

ack

Custom

ers

Energy

to

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DTB

DTB

D

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

(HAN

) for Com

mercial

Custom

ers

Custom

er Service

Enab

lemen

tan

d TB

DPay for

Performan

ceN/A ‐ No curren

t evide

nce

of In

tellectua

l Prope

rty

developm

ent

Sole Sou

rce to Rainforest A

utom

ation for p

urchase

of ene

rgy mon

itorin

g de

vices that con

nect to

the

SmartM

eter™.

TBD

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

through Targeted

Data

Analytics

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Sole Sou

rce to Terad

ata to re

duce unn

ecessary IT

redu

ndan

cy by leveraging existing da

ta platform

and da

ta con

nections ra

ther th

an re

‐create them

.

TBD

AppA-57

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Ap

proa

ches In

to Utility

Plan

ning

Side

Customer Service

Enab

lemen

tan

d TB

DPay for

Performan

ceN/A

Sole Sou

rce to In

tegral Ana

lytics (IA) given

they are

the de

velope

r/vend

or fo

r Loa

dSEER, which is th

e tool th

at is being m

odified

to achieve th

e goals o

f this project.

N/A

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Disaggregatio

n for N

on‐

Resid

entia

l Customers

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DTB

DTB

D

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart

Commun

ications

Grid

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

TBD

TBD

TBD

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Distrib

ution Au

tomation

Ope

n Archite

cture De

v ices

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

N/A

Compe

ititiv

e Bid

11

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Integrated

Smart G

rid

Network Man

agem

ent

Cross‐Cu

tting/Foun

datio

nal

TBD

Pay for

Performan

ceN/A

Compe

titive Bid

8

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Commun

ications

Mon

itorin

gPath

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

N/A

TBD

TBD

V

AppA-58

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv.Treatm

ent o

fIntellectua

l Prope

rty

applicab

le)

(if

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile

Applications

Meter

Cross‐Cu

tting/Foun

datio

nal

TBD

Pay for

Performan

ceProvision

al paten

t filed

for the

multi‐pu

rpose

mob

ile m

eter (N

ext

Gen

eration Meter ‐

NGM).

Compe

titive Bid

8

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to

Participate in In

dustry‐W

ide

RD&D Programs

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DTB

DTB

D

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐


arket

Retail Optim

izatio

n/

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

V

AppA-59

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Match Fun

ding

Split

Fund

ing

Mecha

nism

Intellectua

l Prope

rty

Iden

tification of th

e Metho

d Aw

ards.

Used to Grant

If Co

mpe

titively

Selected

, Provide

the

Num

ber o

f Bidde

rs

Passing the Initial

Pass/Fail Scree

ning fo

r Project

AB

CD

RS

T U

VFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xii. Match

Fund

ing Sp

lit

applicab

le)(if

xiii. Fun

ding

Mecha

nism

(if

applicab

le)

xiv. Treatmen

t of

Intellectua

l Prope

rty

applicab

le)

(if

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

N/A

N/A

N/A

N/A

N/A

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service

Iden

tification

Mom

entary O

Inform

ation

Issue

Leveraging

utage

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

N/A

N/A

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DN/A

TBD

N/A

N/A

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

N/A

N/A

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d TB

DPay for

Performan

ceTB

DN/A

N/A


previou

s ann

ual rep

ort

AppA-60

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.

If Interagency or Sole So

urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

Cupe

rtino Electric

1N/A

Column ap

plicab

le to

CEC

only

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

AppA-61

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Pilot F

acilitie

s for New

En


Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

source Forecast M

etho

ds

to Better P

redict Variable

Rene

wab

les/DE

R Integration

Resource

• 1st a

ward:

Techno

logies

• 2n

d aw

ard: W

eather Decision

Vertum

Partners

• • 1st a

ward: 1

2nd aw

ard: 1

N/A

Column ap

plicab

le to

CEC

only

Resource Outpu

t

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Commun

ication System

s Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

to Ram


d Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

AppA-62

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

System

Safety an

d Re

liability

through New

Data An

alytics

Techniqu

es

Grid

Mod

ernizatio

n Optim

izatio

nan

d Space Time Insig

ht1N/A

Column ap

plicab

le to

CEC

only

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for Existing

Tran

smiss

ion & Distrib

ution

Grid

Mod

ernizatio

n Optim

izatio

nan

d Tw

o vend

ors c

hosen from

RFP:

• Inertia

Switch

• Trayer

The tw

o first.

RFP vend

ors tied for

N/A

Column ap

plicab

le to

CEC

only

Assets: C

lose Proximity

Sw

itching

Issued

Dire

ct Award for R

emote

Solutio

ns. The

y no

t respo

nd to

RF

P, but sh

ortly

after

compe

titive bid process

completed

, the

y an

noun

ced

inde

pend

ent creation of similar

prod

uct.

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Remote Mon

itorin

g an

d Co


Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

Grid

Mod

ernizatio

n Optim

izatio

nan

d Ph

ase

Phase 1:

2: Black an

d Expo

nent

Veach

Phase

Phase 1:

2: 1 1

N/A

Column ap

plicab

le to

CEC

only

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for T&D Assets:

Discrete Series R

eactors

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

Z

AppA-63

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Correctin

g To

ols to Im

prove

System

Records and

Ope

ratio

ns

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Techno

logies th

at Im

prove

Wildlife Safety and

Protect

Assets from

Weather‐

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Related De

grad

ation

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Co

mmun

ication System

s Im

prove Substatio

n Au

tomation an

d

to

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Interope

rability

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Gen

eration" SmartM

eter™

Telecom Network

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

Functio

nalities

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Techno

logies and

Strategies

That Sup

port In

tegrated


Grid

Mod

ernizatio

n Optim

izatio

nan

d BitStew

1N/A

Column ap

plicab

le to

CEC

only

Grid

" Ope

ratio

ns of the

Future

Z

AppA-64

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Vehicle as a Resou

rce to

Improve Grid

Pow

er Qua

lity

and Re

duce Customer

Grid

Mod

ernizatio

n Optim

izatio

nan

d Efficient Driv

etrains, In

c.

(Pha

se 3 ‐ Be

ta Pha

se)

(EDI)

1 (P

hase 3 ‐ Be

ta Pha

se)

N/A

Column ap

plicab

le to

CEC

only

Outages

201st T

rienn

ial (20

12‐201

4)PG

&E



ulti‐

Utility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

SmartM

eter™‐Ena

bled

Data

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only


Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Techniqu

es and

Cap

abilitie

s via the Sm

artM

eter™

Custom

er Service

Enab

lemen

tan

d BitStew & Prim

estone

Tie for first

N/A

Column ap

plicab

le to

CEC

only

Platform

Z

AppA-65

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Be

nefits o

f Providing th

e Co

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Au

tomatic Id

entification of

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

Distrib

uted

Ene

rgy Re

sources


hey

Intercon

nect to

the Grid

to


251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate


ith

Subm

etering for E

Vs to


Flexibility

Custom

er Service

Enab

lemen

tan

d Nexan

t, Inc.

1N/A

Column ap

plicab

le to

CEC

only

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive

Billing W

ith Sub

metering for


Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

Billing Flexibility

AppA-66

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Side

Man

agem

ent (DS

M) for

Tran

smiss

ion an

d

Custom

er Service

Enab

lemen

t and

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

Distrib

ution (T&D) Cost

Redu

ction

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map


ns fo

r DC

Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

Custom

er Service

Enab

lemen

t and

En

ergy and

Econ

omics, En

vironm

ental

Inc. (E

3)1N/A ‐ E3 was th

e scoring vend

or.highest

Column ap

plicab

le to

CEC

only

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t an


nd

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d

Custom

er Service

Enab

lemen

t and

TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Respon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage

the Distrib

ution Grid

on

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

AppA-67

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

GE Alstom

1N/A

Column ap

plicab

le to

CEC

only

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

Z

AppA-68

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

A

Prog

ram

Administrator

B

Project N

ame

C

Project T

ype

D

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Vehicle to Hom

e

Rene

wab

les/DE

R Re

source

Integration

Navigan

t1N/A

Column ap

plicab

le to

CEC

only

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g &

Volta

ge Tracking

Rene

wab

les/DE

R Re

source

Integration

Nexan

t, Inc.

1N/A

Column ap

plicab

le to

CEC

only

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Emulation for D

G Im

pact

Improvem

ent

Rene

wab

les/DE

R Re

source

Integration

NRE

L1N/A

Column ap

plicab

le to

CEC

only

AppA-69

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

N/A

TBD

TBD

Column ap

plicab

le to

CEC

only

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d Trove Pred

ictiv

e Da

ta1N/A

Column ap

plicab

le to

CEC

only

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d IBM

1N/A

Column ap

plicab

le to

CEC

only

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

AppA-70

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Man

agem

ent M

obile

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Substatio

n/Substatio

n Au

tomation

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically

Phasing Inform

ationMap

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Applications fo

r Gen

erator

Dyna

mic M

odel Validation

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Synchrop

hasor A

nalytics

Applications

&

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Disturba

nce (GMD)

Evalua

tion

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Tran

sformers a

nd Sen

sors

Protectio

n an

d Co

ntrol

for Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

System

s

AppA-71

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

De

man

d‐Side

Strategies &

Techno

logies

Custom

er Service

Enab

lemen

tan

d Solar C

ity (for re

siden

tial

custom

ers);

Green

Cha

rge Networks (for

commercial customers)

1N/A

Column ap

plicab

le to

CEC

only

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e Usage Feedb

ack

Custom

ers

Energy

to

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

(HAN

) for Com

mercial

Custom

ers

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

through Targeted

Data

Analytics

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

Z

AppA-72

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Ap

proa

ches In

to Utility

Plan

ning

Side

Customer Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Disaggregatio

n for N

on‐

Resid

entia

l Customers

Custom

er Service

Enab

lemen

tan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart

Commun

ications

Grid

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Distrib

ution Au

tomation

Ope

n Archite

cture De

vices

Cross‐Cu

tting/Foun

datio

nal

Errig

al In

c.

2Supp

lier selected ha

d be

st

prices fo

r Use Cases th

at were

selected

for a

ward.

Column ap

plicab

le to

CEC

only

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Integrated

Smart G

rid

Network Man

agem

ent

Cross‐Cu

tting/Foun

datio

nal

Errig

al In

c.1N/A

Column ap

plicab

le to

CEC

only

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Commun

ications Path

Cross‐Cu

tting/Foun

datio

nal

TBD

TBD

TBD

Column ap

plicab

le to

CEC

only

Mon

itorin

g

Z

AppA-73

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YZ

For

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile

Applications

Meter

Cross‐Cu

tting/Foun

datio

nal

Ofer C

ommun

ications

1N/A

Column ap

plicab

le to

CEC

only

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to

Participate in In

dustry‐W

ide

RD&D Programs

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DTB

DTB

DCo

lumn ap

plicab

le to

CEC

only

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐


arket

Retail Optim

izatio

n/

Rene

wab

les/DE

R Integration

Resource

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

AppA-74

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

If Co

mpe

titively Selected

, Prov

ide the Nam

e of Selected

Bidd

er.

If Co

mpe

titively Selected

, Prov

ide the Ra

nk of the

Selected

Bidde

r in the

Selection Process.

If Co

mpe

titively Selected

, Explain Why th

e Bidd

er W

as

Not th

e Highe

st Scorin

g Bidd

er, Explain W

hy a Low

er

Scoring Bidd

er W

as Selected.


urce

Agreem

ent, Sp

ecify

Date of

Notificatio

n to th

e Joint

Legislative Bu

dget

Committee (JLBC) W

as

Notified

and

Date of JLBC

Au

thorization.

AB

CD

WX

YFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service

Iden

tification

Mom

entary O

Inform

ation

Issue

Leveraging

utage

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d N/A

N/A

N/A

Column ap

plicab

le to

CEC

only


previou

s ann

ual rep

ort

Z

AppA-75

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How

the Project Leads to

Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

Yes.

•Pow

er Settle

men

ts

based

• Trim

ark Associates

Consultin

g ‐ C

alifo

rnia‐

‐ Ca

lifornia‐ba

sed

Column ap

plicab

le to

CEC

only

• 1i ‐ Nam

eplate cap

acity

(megaw

atts) o

f grid

‐con

nected

ene

rgy storage.

• 3a ‐ Maintain/Re

duce ope

ratio

ns and

mainten

ance costs.

• 6a ‐ CA

ISO NGR fin

ancial se

ttlemen

ts.

• 7b

‐ Increased use of cost‐effective digital information an

d control

techno

logy to

improve reliability, se

curity, and

efficien

cy of the

electric grid

(Pub

lic Utilities Cod

e (Pub

. Util. C

ode) § 836

0).

• 7c ‐ Dy

namic optim

izatio

n of grid

ope

ratio

ns and

resources, includ

ing

approp

riate con

sideration for a

sset m

anagem

ent a

nd utiliza

tion of re

lated

grid ope

ratio

ns and

resources, with

cost‐effective full cybe

r security

(Pub

. Util.

Code

§ 836

0).

• 7l ‐ Iden

tification an

d lowering of unreasona

ble or unn

ecessary barrie

rs to

ad

optio

n of sm

art g

rid te

chno

logies, p

ractices, and

services (P

ub. U

til. C

ode §

8360

).• 9c ‐ EP

IC project re

sults re

ferenced

in re

gulatory proceed

ings and

policy

repo

rts (Bu

siness P

lan references: CP

UC R.10

‐12‐00

7).

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

Yes ‐ Califo

rnia‐based

.Co

lumn ap

plicab

le to

CEC

only

• 1c ‐ Av

oide

d procurem

ent a

nd gen

eration costs.

• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(Pub

lic Utilities Cod

e (Pub

. Util. C

ode) § 836

0).

• 7d

‐ De

ploymen

t and

integration of cost‐effective distrib

uted

resources a

nd

gene

ratio

n, includ

ing rene

wab

le re

sources (Pu

b. Util. C

ode § 83

60).

• 9c ‐ EP

IC project re

sults re

ferenced

in re

gulatory proceed

ings and

policy

repo

rts (Bu

siness P

lan references: De

ferring a capa

city upgrade

has been

iden

tified as a key poten

tial value

of E

nergy Storage Techno

logies (E

STs) and

no

ted in filings with

the CP

UC/Assembly Bill 25

14.

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

TBD

Column ap

plicab

le to

CEC

only

AppA-76

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Re

newab

les/DE

R Re

source

N/A

Column ap

plicab

le to

CEC

only

N/A

Pilot F

acilitie

s for New

Integration

Energy Storage Systems.

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

newab

les/DE

R Re

source

• Weather Decision

Techn

ologies: No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Resource Forecast M

etho

ds Integration

• Ve

rtum

Partners: Yes ‐ Ca

lifornia‐ba

sed

• 4a ‐ GHG

emiss

ions re

ductions (M

MTC

O2e

).to Better P

redict Variable

• Clean Po

wer Research: Yes ‐ Ca

lifornia‐

• 5c ‐ Forecast accuracy im

provem

ent.

Resource Outpu

tba

sed

• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Rene

wab

les/DE

R Re

source

TBD

Column ap

plicab

le to

CEC

only

N/A

Commun

ication System

s Integration

Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

Rene

wab

les/DE

R Re

source

N/A

Column ap

plicab

le to

CEC

only

N/A

to Ram


d Integration

Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

AppA-77

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

Grid

Mod

ernizatio

n an

d Yes ‐ Califo

rnia‐based

Column ap

plicab

le to

CEC

only

• 7c ‐ Dy

namic optim

izatio

n of grid

ope

ratio

ns and

resources; includ

ing

System

Safety an

d Re

liability

Optim

izatio

nap

prop

riate con

sideration for a

sset m

anagem

ent a

nd utiliza

tion of re

lated

through New

Data An

alytics

grid ope

ratio

ns and

resource, w

ith cost‐effective full cybe

r security

(Pub

lic

Techniqu

esUtilities Cod

e §8

360).


duce ope

ratio

ns and

mainten

ance costs: With

the

improved

und

erstan

ding of risk

, the

re cou

ld be a be

tter to

ol fo

r evaluating

projects su

ch as a

sset re

placem

ent.

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only

• 5a ‐ Outage nu

mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Mon

itorin

g an

d Co

ntrol

Optim

izatio

n• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

System

s for Existing

Tran

smiss

ion & Distrib

ution

Assets: C

lose Proximity

Sw

itching

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Remote Mon

itorin

g an

d Optim

izatio

n• 3b

‐ Maintain/Re

duce cap

ital costs.

Control Systems for T&D

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

Assets / De

mon

strate New

• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Mon

itorin

g an

d Co

ntrol

Optim

izatio

n• 3b

‐ Maintain/Re

duce cap

ital costs.

System

s for T&D Assets:


mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Discrete Series R

eactors

• 5b

‐ Electric sy

stem

pow

er flow

con

gestion redu

ction.

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Automated

Asset

Optim

izatio

nNotificatio

n an

d Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

AppA-78

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Automated

Asset

Optim

izatio

nNotificatio

n an

d Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Correctin

g To

ols to Im

prove

Optim

izatio

nSystem

Records and

Ope

ratio

ns

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Techno

logies th

at Im

prove

Optim

izatio

nWildlife Safety and

Protect

Assets from

Weather‐

Related De

grad

ation

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Commun

ication System

s to

Optim

izatio

nIm

prove Substatio

n Au

tomation an

d Interope

rability

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only

• 7f ‐ De

ploymen

t of cost‐effective sm

art techn

ologies, includ

ing real time,

Gen

eration" SmartM

eter™

Optim

izatio

nau

tomated

, interactiv

e techno

logies th

at optim

ize th

e ph

ysical ope

ratio

n of

Telecom Network

appliance an

d consum

er devices fo

r metering, com

mun

ications con

cerning

Functio

nalities

grid ope

ratio

ns and

status, and

distrib

ution au

tomation (Pub

lic Utilities Cod

e (Pub

. Util. C

ode) §83

60).

• 7k ‐ De

velop stan

dards for com

mun

ication an

d interope

rability of app

liances

and eq

uipm

ent con

nected

to th

e electric grid

, including th

e infrastructure

serving the grid (P

ub. U

til. C

ode §8

360).

• Note: Each techno

logy dem

onstrated may have ad

ditio

nal spe

cific ben

efits

to nam

e. For instan

ce, the

following could ap

ply: improved

com

mun

ication

for p

ower re

storation, im

proved

con

trol of streetlights, etc.

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only


mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Techno

logies and

Strategies

Optim

izatio

n• 7b


d control

That Sup

port In

tegrated

techno

logy to


curity an

d efficiency of th

e electric grid


(Pub

lic Utilities Cod

e 83

60).

Grid

" Ope

ratio

ns of the


duce ope

ratio

ns and

mainten

ance costs.

Future

AppA-79

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

191st T

rienn

ial (20

12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Grid

Mod

ernizatio

n an

d N/A

Column ap

plicab

le to

CEC

only


mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Vehicle as a Resou

rce to

Optim

izatio

n• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

Improve Grid

Pow

er Qua

lity


duce ope

ratio

ns and

mainten

ance costs.

and Re

duce Customer

• 4a – Green

house Gas emiss

ions re

ductions (M

MTC

O2e

).Outages

201st T

rienn

ial (20

12‐201

4)PG

&E


s Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

by Participating in M

ulti‐

Optim

izatio

nUtility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

Custom

er Service and

No

Column ap

plicab

le to

CEC

only

• 1f ‐ Av

oide

d custom

er ene

rgy use.

SmartM

eter™‐Ena

bled

Data

Enab

lemen

t• 1h

‐ Cu

stom

er bill sa

vings (do

llars sa

ved).


Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Custom

er Service and

No

Column ap

plicab

le to

CEC

only

• 1h

‐ Cu

stom

er bill sa

vings (do

llars sa

ved).

Techniqu

es and

Cap

abilitie

s En

ablemen

t• 1f ‐ Av

oide

d custom

er ene

rgy use (kilowatt‐ho

urs s

aved

).via the Sm

artM

eter™


duce ope

ratio

ns and

mainten

ance costs.

Platform

• 3b

‐ Maintain/Re

duce cap

ital costs.

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

• 5f ‐ Re

duced flicker and

other pow

er qua

lity diffe

rences.

• 5i. Increase in th

e nu

mbe

r of n

odes in th

e po

wer sy

stem

at m

onito

ring

points.

• 7f ‐ De

ploymen

t of cost‐effective sm

art techn

ologies, includ

ing real time,

automated

, interactiv

e techno

logies th

at optim

ize th

e ph

ysical ope

ratio

n of

appliance an

d consum

er devices fo

r metering, com

mun

ications con

cerning

grid ope

ratio

ns and

status, and

distrib

ution au

tomation.

• 7b


d control

techno

logy to


curity an

d efficiency of th

e electric grid

.

AppA-80

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

231st T

rienn

ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Cu

stom

er Service and

N/A

Column ap

plicab

le to

CEC

only

N/A

Bene

fits o

f Providing th

e En

ablemen

tCo

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Cu

stom

er Service and

No

Column ap

plicab

le to

CEC

only

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

Automatic Id

entification of

Enab

lemen

t• 5f ‐ Re

duced flicker and

other pow

er qua

lity diffe

rences.

Distrib

uted

Ene

rgy Re

sources


provem

ent.


hey

Intercon

nect to

the Grid

to


251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate

Custom

er Service and

No

Column ap

plicab

le to

CEC

only

• 4a ‐ GHG

emiss

ions re

ductions (M

MTC

O2e

).Subtractive Billing W

ith

Enab

lemen

t• 1h

‐ Cu

stom

er bill sa

vings (megaw

att h

ours sa

ved).

Subm

etering for E

Vs to


Flexibility

261st T

rienn

ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive Cu

stom

er Service and

Opo

wer ‐ No

Column ap

plicab

le to

CEC

only


provem

ents.

Billing W

ith Sub

metering for

Enab

lemen

tClean Po

wer Research ‐ Y

es: C

alifo

rnia‐based

• 7b


d control


techno

logy to


curity an

d efficiency of th

e electric grid

Billing Flexibility

(Pub

lic Utilities Cod

e 83

60).

AppA-81

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

271st T

rienn

ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Custom

er Service and

No

Column ap

plicab

le to

CEC

only

• 7b


d control

Side

Man

agem

ent (DS

M) for En

ablemen

ttechno

logy to


curity an

d efficiency of th

e electric grid

Tran

smiss

ion an

d (Pub

lic Utilities Cod

e 83

60).

Distrib

ution (T&D) Cost

Redu

ction

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map C

ustomer Service and

Yes ‐ Califo

rnia‐based

, sm

all business, and

Co

lumn ap

plicab

le to

CEC

only


duce cap

ital costs.


ns fo

r En

ablemen

tMinority

Based

Enterprise

(MBE

).• 3d

‐ Num

ber o

f ope

ratio

ns of various existing eq

uipm

ent types before an

dDC

Fast C

harging, Based

on

after a

doption of a new

smart g

rid com

pone

nt, as a

n indicator o

f possib

le

Traffic Patterns a

nd PG&E's

equipm

ent life

exten

sions from

redu

ced wear a

nd te

ar.

Distrib

ution System

, to

• 4a ‐ Green

house Gas emiss

ions re

ductions (M

MTC

O2e

).Ad

dress E

V Drivers' Needs


provem

ent.

While Red

ucing the Im

pact

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

on PG&E's D

istrib

ution Grid

• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(Pub

lic Utilities Cod

e § 83

60).

• 7l ‐ Iden

tification an


ble or unn

ecessary barrie

rs to

adop

tion of sm

art g

rid te

chno

logies, p

ractices, and

services.

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t Cu

stom

er Service and

TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

and Telemetry Strategies a

nd Ena

blem

ent

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d Re

spon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage on

Rene

wab

les/DE

R Re

source

TBD

Column ap

plicab

le to

CEC

only

TBD

the Distrib

ution Grid

Integration

AppA-82

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

No

Column ap

plicab

le to

CEC

only

• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(Pub

lic Utilities Cod

e (Pub

. Util. C

ode) § 836

0).

• 7d

‐ De

ploymen

t and


uted

resources a

ndgene

ratio

n, includ

ing rene

wab

le re

sources (Pu

b. Util. C

ode § 83

60).

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

TBD

Column ap

plicab

le to

CEC

only

•3a ‐ Maintain/Re

duce ope

ratio

ns and

mainten

ance costs.

• 7d

‐ De

ploymen

t and


uted

gene

ratio

n, includ

ing rene

wab

le re

sources.

resources a

nd

AppA-83

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Rene

wab

les/DE

R Re

source

No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Enha

nced

Cap

abilitie

s ‐

Integration

• 7d

‐ De

ploymen

t and


uted

resources a

nd

Vehicle to Hom

egene

ratio

n, includ

ing rene

wab

le re

sources.

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g &

Rene

wab

les/DE

R Re

source

No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Volta

ge Tracking

Integration

• 7b


d control

techno

logy to


curity an

d efficiency of th

e electric grid

(Pub

lic Utilities Cod

e 83

60).

• 7d

‐ De

ploymen

t and


uted

resources a

nd

gene

ratio

n, includ

ing rene

wab

le re

sources.

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Rene

wab

les/DE

R Re

source

No

Column ap

plicab

le to

CEC

only

• 1a. N

umbe

r and

total nam

eplate cap

acity

of d

istrib

uted

gen

eration facilities

Emulation for D

G Im

pact

Integration

• 1b

. Total electric

ity deliveries from grid

‐con

nected

distrib

uted

gen

eration

Improvem

ent

facilities

• 1i. N

amep

late cap

acity

(MW) o

f grid

‐con

nected

ene

rgy storage

• 3e

. Non

‐ene

rgy econ

omic ben

efits (reliability)

• 5a. O

utage nu

mbe

r, freq

uency an

d du

ratio

n redu

ctions

• 7b

. Increased

use of cost‐effective digital information an

d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(PU Cod

e § 83

60)

• 7d

. Dep

loym

ent a

nd integration of cost‐effective distrib

uted

resources a

nd

gene

ratio

n, includ

ing rene

wab

le re

sources (PU

Cod

e § 83

60)

• 7h

. Dep

loym

ent a

nd integration of cost‐effective ad

vanced

electric

ity

storage an

d pe

ak‐sha

ving te

chno

logies, including plug‐in electric and

hybrid

electric veh

icles, and

thermal‐storage air‐cond

ition

ing (PU Cod

e § 83

60)

AppA-84

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

N/A

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

• 3b

‐ Maintain/Re

duce cap

ital costs.

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

• 7k ‐ De

velop stan

dards for com

mun

ication an

d interope

rability of app

liances

and eq

uipm

ent con

nected

to th

e electric grid

, including th

e infrastructure

serving the grid.

• 7l ‐ Iden

tification an


ble or unn

ecessary barrie

rs to

ad

optio

n of sm

art g

rid te

chno

logies, p

ractices, and

services.

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d No

Column ap

plicab

le to

CEC

only

• 7b

‐ Increased use of

techno

logy to

improve cost‐effe

ctive digital information an

d control

reliability, se

curity, and

efficien

cy of the

electric grid

.

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d No

Column ap

plicab

le to

CEC

only

• • • • • •

3a ‐ Maintain/Re

duce ope

ratio

ns and

mainten

ance costs.

4a ‐ Green

house Gas emiss

ions re

ductions (M

MTC

O2e

).5a ‐ Outage nu

mbe

r, freq

uency an

d du

ratio

n redu

ctions.

5d ‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

5c ‐ Forecast accuracy im

provem

ent.

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

AppA-85

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Man

agem

ent M

obile

Optim

izatio

nAp

plications

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Substatio

n/Substatio

n Optim

izatio

nAu

tomation

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically M

ap

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

• 7b


d control

Phasing Inform

ation

Optim

izatio

ntechno

logy to


curity, and

efficien

cy of the

electric grid

.

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Grid

Mod

ernizatio

n an

d No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Applications fo

r Gen

erator

Optim

izatio

n• 5a ‐ Outage nu

mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Dyna

mic M

odel Validation

• 7b


d control

techno

logy to


curity an

d efficiency of th

e electric grid

(Pub

lic Utilities Cod

e 83

60).

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Synchrop

hasor A

nalytics &

Optim

izatio

nAp

plications

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Disturba

nce (GMD)

Optim

izatio

nEvalua

tion

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Grid

Mod

ernizatio

n an

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Tran

sformers a

nd Sen

sors fo

r Optim

izatio

nProtectio

n an

d Co

ntrol

System

s

AppA-86

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

Cu

stom

er Service and

No

Column ap

plicab

le to

CEC

only

•1c ‐ Av

oide

d procurem

ent a

nd gen

eration costs.

Deman

d‐Side

Strategies &

En

ablemen

t• 1i ‐ Nam

eplate Cap

acity

of G

rid‐Con

nected

Storage.

Techno

logies

• 3f ‐ Im

provem

ents in sy

stem

ope

ratio

n efficiencies s

temming from

increased utility disp

atchab

ility of customer dem

and sid

e man

agem

ent.

• 5b

‐ Electric sy

stem

pow

er flow

con

gestion redu

ction.

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

.• 7d

‐ De

ploymen

t and


uted

resources a

ndgene

ratio

n, includ

ing rene

wab

le re

sources.

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e En

ergy

Custom

er Service and

TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Usage Feedb

ack to

Enab

lemen

tCu

stom

ers

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

Custom

er Service and

TB

DCo

lumn ap

plicab

le to

CEC

only

•1e ‐ Pe

ak load re

duction (m

egaw

atts) from su

mmer and

winter p

rogram

s.(HAN

) for Com

mercial

Enab

lemen

t•1f ‐ Av

oide

d custom

er ene

rgy use (kilowatt h

ours sa

ved).

Custom

ers

• 1h

‐ Cu

stom

er bill sa

vings (do

llars sa

ved).

• 3a ‐ Maintain / R

educe op

erations and

mainten

ance costs.

• 4a ‐ GHG

emiss

ions re

ductions (M

MTC

O2e

).• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(Pub

lic Utilities Cod

e § 83

60).

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

Custom

er Service and

TB

DCo

lumn ap

plicab

le to

CEC

only


duce cap

ital costs.

through Targeted

Data

Enab

lemen

t• 7b


d control

Analytics

techno

logy to


curity, and

efficien

cy of the

electric grid

.• 7e ‐ De

velopm

ent a

nd incorporation of cost‐effective de

man

d respon

se,

deman

d sid

e resource, and

ene

rgy efficient re

sources.

• 7h

‐ De

ploymen

t and

integration of cost‐effective ad

vanced

electric

ity

storage an

d pe

ak‐sha

ving te

chno

logies.

AppA-87

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Side

Customer Service and

No

Column ap

plicab

le to

CEC

only

•1c ‐ Av

oide

d procurem

ent a

nd gen

eration costs.

Approa

ches In

to Utility

En

ablemen

t• 3f ‐ Im

provem

ents in sy

stem

ope

ratio

n efficiencies s

temming from

Plan

ning


atchab


and sid

e man

agem

ent.


provem

ent.

• 7e ‐ De

velopm

ent a

nd incorporation of cost‐effective de

man

d respon

se,

deman

d sid

e resources, and

ene

rgy‐efficient re

sources (Pu

blic Utilities Cod

e §

8360

).

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Custom

er Service and

TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

Disaggregatio

n for N

on‐

Enab

lemen

tRe

siden

tial Customers

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart G

rid

Cross‐Cu

tting/Foun

datio

nal

TBD

Column ap

plicab

le to

CEC

only

TBD

Commun

ications

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Cross‐Cu

tting/Foun

datio

nal

No

Column ap

plicab

le to

CEC

only

• 3f ‐ Im

provem

ents in sy

stem

ope

ratio

n efficiencies s

temming from

Distrib

ution Au

tomation


atchab


and sid

e man

agem

ent.

Ope

n Archite

cture De

vices

• 5i ‐ Increase in th

e nu

mbe

r of n

odes in th

e po

wer sy

stem

at m

onito

ring

points.

• 7j ‐ Provide consum

ers w

ith timely inform

ation an

d control options.

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Cross‐Cu

tting/Foun

datio

nal

Yes

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs.

Integrated

Smart G

rid


mbe

r, freq

uency an

d du

ratio

n redu

ctions.

Network Man

agem

ent

• 5d

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction.

• 5e ‐ Utility

worker safety im

provem

ent a

nd hazard expo

sure re

duction.

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Cross‐Cu

tting/Foun

datio

nal

TBD

Column ap

plicab

le to

CEC

only

• 1h

‐ Cu

stom

er bill sa

vings (do

llars sa

ved).

Commun

ications Path

• 3e ‐ Non

‐ene

rgy econ

omic ben

efits – re

duction op

erationa

l hou

rs to

fix

Mon

itorin

gestim

ated

bills d

ue to

RF Interferen

ce.

AppA-88

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile

Applications

Meter

Cross‐Cu

tting/Foun

datio

nal

No

Column ap

plicab

le to

CEC

only


duce ope

ratio

ns and

mainten

ance costs (A

ffordab

ility).

• 7b


d control

techno

logy to


curity, and

efficien

cy of the

electric grid

(Reliability).

• 7j ‐ Provide consum

ers w

ith timely inform

ation an

d control options

(Customer).

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to

Participate in In

dustry‐W

ide

RD&D Programs

Grid

Mod

ernizatio

n Optim

izatio

nan

d TB

DCo

lumn ap

plicab

le to

CEC

only

TBD

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐


arket

Retail Optim

izatio

n/

Rene

wab

les/DE

R Integration

Resource

N/A

Column ap

plicab

le to

CEC

only

N/A

AppA-89

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

Doe

s Award Re

cipien

t Ide

ntify

as C

alifo

rnia‐

Based En

tity, Small B

usiness, Businesses

Owne

d by W

omen

, Minorities, o

r Disab

led

Veterans?

Inform

ation Re

quested for T

echn

olog

y Ve

ndor Procuremen

ts Only (i.e., N

ot PMs,

Consultin

g Services, Etc.)

How


Techno

logical A

dvan

cemen

t or

Breakthrou

ghs to Overcom

e Ba

rriers to

Achieving th

e State's S

tatutory Ene

rgy Goa

ls

Applicab

le M

etric

s

AB

CD

AAAB

ACFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

vi. M

etric

s

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

N/A

Column ap

plicab

le to

CEC

only

N/A

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service

Iden

tification

Mom

entary O

Inform

ation

Issue

Leveraging

utage

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

Column ap

plicab

le to

CEC

only

N/A

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

Column ap

plicab

le to

CEC

only

•3a

• 5a

• 5d

‐ Maintain / R

educe op

erations and

mainten

ance costs

‐ Outage nu

mbe

r, freq

uency an

d du

ratio

n redu

ctions

‐ Pu

blic sa

fety im

provem

ent a

nd hazard expo

sure re

duction

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d N/A

Column ap

plicab

le to

CEC

only

N/A

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d N/A

Column ap

plicab

le to

CEC

only

• Time

impa

ct to

of co

mplete the process o

f designing,

a hypo

thetical ra

te design

optim

izing, and

ana

lyzin

g the


previou

s ann

ual rep

ort

AppA-90

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

11st T

rienn

ial (20

12‐201

4)PG

&E

1.01 ‐

UsesEn

ergy Storage End

Re

newab

les/DE

R Integration

Resource

• • Project com

pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

21st T

rienn

ial (20

12‐201

4)PG

&E

1.02 ‐ De

mon

strate th

e Use

of Distrib

uted

Ene

rgy Storage

for T

&D Co

st Red

uctio

n

Rene

wab

les/DE

R Integration

Resource

•• Project com

pleted

in Feb

ruary 20

18• Th

is project d

emon

strated the ab

ility of u

tility

‐owne

d an

d controlled en

ergy storage resources to de

liver auton

omou

s distrib

ution

peak sh

aving functio

nality. Ene

rgy storage resources h

old sig

nifican

t promise

to help Ca

lifornia ad

dress a

variety of g

rid plann

ing an

d op

erations cha

llenges, b

oth toda

y an

d in th

e future. The

implem

entatio

n an

d op

erationa

l cha

llenges associated with

this project

resulte

d in learnings tha

t will inform

PG&E’s p

rocuremen

t of future en

ergy storage resources, both utility‐owne

d an

d utility‐con

tracted ,

through compliance with

the IOU ene

rgy procurem

ent targets as s

et fo

rth in CPU

C D. 10‐03

‐040 and

beyon

d.• Fina

l Rep

ort include

d in th

is 20

17 EPIC An

nual Rep

ort

31st T

rienn

ial (20

12‐201

4)PG

&E

1.03 ‐ De

mon

strate Prio

rity

Scen

arios from th

e En

ergy

Storage Fram

ework

Rene

wab

les/DE

R Integration

Resource

• Project is c

urrently on‐ho

ld.

AppA-91

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

41st T

rienn

ial (20

12‐201

4)PG

&E

1.04 ‐ Expa

nd Test Lab and

Pilot F

acilitie

s for New

En


Rene

wab

les/DE

R Integration

Resource

• Form

ally W

ithdraw

n. CPU

C A.12

‐11‐00

3, 10/15

/201

3.

51st T

rienn

ial (20

12‐201

4)PG

&E

1.05 ‐ De

mon

strate New

Re

source Forecast M

etho

ds

to Better P

redict Variable

Rene

wab

les/DE

R Integration

Resource

• • Project com

pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Resource Outpu

t

61st T

rienn

ial (20

12‐201

4)PG

&E

1.06 ‐ De

mon

strate

Commun

ication System

s Allowing the CA

ISO to

Utilize

Av

ailable Re

newab

le

Rene

wab

les/DE

R Integration

Resource

• Project is c

urrently on‐ho

ld.

Gen

eration Flexibility

71st T

rienn

ial (20

12‐201

4)PG

&E

1.07 ‐ De

mon

strate Systems

to Ram


d Gen


Ad

apt to Ch

anges in Va

riable

Energy Resou

rces Outpu

t

Rene

wab

les/DE

R Integration

Resource

• Form

ally W

ithdraw

n.

CP

UCA.12

‐11‐00

3, 10/15

/201

3.

AppA-92

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

81st T

rienn

ial (20

12‐201

4)PG

&E

1.08 ‐ Im

prove Distrib

ution

System

Safety an

d Re

liability

through New

Data An

alytics

Techniqu

es

Grid

Mod

ernizatio

n Optim

izatio

nan

d • • Project com

pleted

in

Fina

l rep

ort include

d 20

15.

in previou

s 201

5 EP

IC Ann

ual Rep

ort.

91st T

rienn

ial (20

12‐201

4)PG

&E

1.09

A ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for Existing

Tran

smiss

ion & Distrib

ution

Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Assets: C

lose Proximity

Sw

itching

101st T

rienn

ial (20

12‐201

4)PG

&E

1.09

B an

d 1.10

B ‐ T

est N

ew

Remote Mon

itorin

g an

d Co


Assets / De

mon

strate New

Strategies and

Techn

ologies

to Im


Existing Mainten

ance and

Re

placem

ent P

rogram

s

Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

111st T

rienn

ial (20

12‐201

4)PG

&E

1.09

C ‐ T

est N

ew Rem

ote

Mon

itorin

g an

d Co

ntrol

System

s for T&D Assets:

Discrete Series R

eactors

Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

121st T

rienn

ial (20

12‐201

4)PG

&E

1.10

A ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

Man

agem

ent S

ystems:

Dissolved Gas Ana

lysis

AppA-93

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

131st T

rienn

ial (20

12‐201

4)PG

&E

1.10

C ‐ D

emon

strate

Automated

Asset

Notificatio

n an

d

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

Man

agem

ent S

ystems:

Und

ergrou

nd Cab

le Ana

lysis

141st T

rienn

ial (20

12‐201

4)PG

&E

1.11 ‐ De

mon

strate Self‐

Correctin

g To

ols to Im

prove

System

Records and

Ope

ratio

ns

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

151st T

rienn

ial (20

12‐201

4)PG

&E

1.12 ‐ De

mon

strate New

Techno

logies th

at Im

prove

Wildlife Safety and

Protect

Assets from

Weather‐

Grid

Mod

ernizatio

n Optim

izatio

nan

d •Project is c

urrently on‐ho

ld.

Related De

grad

ation

161st T

rienn

ial (20

12‐201

4)PG

&E

1.13 ‐ De

mon

strate New

Co

mmun

ication System

s Im

prove Substatio

n Au

tomation an

d

to

Grid

Mod

ernizatio

n Optim

izatio

nan

d •Project is c

urrently on‐ho

ld.

Interope

rability

171st T

rienn

ial (20

12‐201

4)PG

&E

1.14 ‐ De

mon

strate "Next

Gen

eration" SmartM

eter™

Telecom Network

Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Functio

nalities

181st T

rienn

ial (20

12‐201

4)PG

&E

1.15 ‐ De

mon

strate New

Techno

logies and

Strategies

That Sup

port In

tegrated


Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Grid

" Ope

ratio

ns of the

Future

AppA-94

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

191st T

rienn

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12‐201

4)PG

&E

1.16 ‐ De

mon

strate Electric

Vehicle as a Resou

rce to

Improve Grid

Pow

er Qua

lity

and Re

duce Customer

Grid

Mod

ernizatio

n Optim

izatio

nan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Outages

201st T

rienn

ial (20

12‐201

4)PG

&E



ulti‐

Utility

, Ind

ustry Wide RD

&D

Programs S

uch as EPR

I

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

211st T

rienn

ial (20

12‐201

4)PG

&E

1.18 ‐ De

mon

strate

SmartM

eter™‐Ena

bled

Data


Custom

ers W

ith App

liance‐

Level Ene

rgy Use In

form

ation

Custom

er Service

Enab

lemen

tan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

221st T

rienn

ial (20

12‐201

4)PG

&E

1.19 ‐ Pilot E

nhan

ced Da

ta

Techniqu

es and

Cap

abilitie

s via the Sm

artM

eter™

Custom

er Service

Enab

lemen

tan


pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Platform

AppA-95

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

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RG

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ram

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AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

231st T

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ial (20

12‐201

4)PG

&E

1.20 ‐ De

mon

strate th

e Cu

stom

er Service and

• Form

ally notified

CPU

C on

10‐31

‐13, project m

ay be term

inated

as refined

scop

e do

es not app

ear to meet safety, re

liability,

Bene

fits o

f Providing th

e En

ablemen

taffordab

ility guiding prin

ciples fo

r prio

rity Re

search and

Develop

men

t.Co

mpe

titive, Ope

n Market

With

Autom

ated

Access to

Custom

er‐Autho

rized

Sm

artM


e Inno

vatio

n.

241st T

rienn

ial (20

12‐201

4)PG

&E

1.21 ‐ Pilot M

etho

ds fo

r Cu

stom

er Service and

• Project com

pleted

in 201

6.Au

tomatic Id

entification of

Enab

lemen

t• Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Distrib

uted

Ene

rgy Re

sources


hey

Intercon

nect to

the Grid

to


251st T

rienn

ial (20

12‐201

4)PG

&E

1.22 ‐ De

mon

strate

Custom

er Service and

•• Project is in the Bu

ild/Test p

hase.


ith

Enab

lemen

t• Ph

ase 1 evalua

tion repo

rt re

leased

in 201

6, project re

ceived

CPU

C ap

proval fo

r lau

nch of Pha

se 2, add

ing an add

ition

al business

Subm

etering for E

Vs to

mod

el fo

r the

MDM

A to hold contracts w

ith customers b

e respon

sible fo

r the

EV bill to PG&E.


• Ph

ase 2 commen

ced Janu

ary 1, 201

7 with

4 out of 6

app

roved MDM

As con

firmed

for p

articipation an

d en

ded Ap

ril 30, 201

7, yielding

Flexibility

264 of th

e expe

cted

500

customer enrollm

ent g

oal.

• Co

mpleted

data loggers installatio

n on

subm

eters in pa

rticipan

t hom

es to

provide

accuracy da

ta fo

r overall evalua

tion

• Presen

ted pa

rticipan

t welcome survey to

CPU

C with

the following fin

dings; PG&E achieved

an 85

% re

spon

se ra

te on survey, 55%

of

Phase I p

articipan

t ind

icated

that th

e Ph

ase II expe

rience ha

s been be

tter, 45%

of respo

nden

ts re

ported

switching to

cha

rging off‐p

eak

durin

g the de

mon

stratio

n• Next steps includ

e continua

tion of processing MDM

A incentive pa

ymen

ts, d

e‐en

roll pa

rticipan

ts and

decom

miss

ion subm

eters, draft

and pu

blish

Final Rep

ort

261st T

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ial (20

12‐201

4)PG

&E

1.23 ‐ De

mon

strate Add

itive Cu

stom

er Service and

• Project com

pleted

in 201

6.Billing W

ith Sub

metering for

Enab

lemen

t• Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.


Billing Flexibility

Project N

ame

Project T

ype

2017 Upd

ate

AppA-96

AD

xv. 2

017 Status Upd

ate

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

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NN

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EPO

RT

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NTI

NU

ED)

Row #

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ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

271st T

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ial (20

12‐201

4)PG

&E

1.24 ‐ De

mon

strate Dem

and‐

Side

Man

agem

ent (DS

M) for

Tran

smiss

ion an

d

Custom

er Service

Enab

lemen

t and

• • Project com

pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Distrib

ution (T&D) Cost

Redu

ction

281st T

rienn

ial (20

12‐201

4)PG

&E

1.25 ‐ De

velop a To

ol to

Map


ns fo

r DC

Fast C

harging, Based

on

Traffic Patterns a

nd PG&E's

Custom

er Service

Enab

lemen

t and

• • Project com

pleted

in 201

6.Fina

l Rep

ort w

as includ

ed in 201

6 EP

IC Ann

ual Rep

ort.

Distrib

ution System

, to

Address E

V Drivers' Needs

While Red

ucing the Im

pact

on PG&E's D

istrib

ution Grid

291st T

rienn

ial (20

12‐201

4)PG

&E

1.26 ‐ Pilot M

easuremen

t an


nd

Techno

logies Tha

t Ena

ble the

Cost‐Effe


Mass M

arket D

eman

d

Custom

er Service

Enab

lemen

t and

• Project is c

urrently on‐ho

ld.

Respon

se (D

R) Resou

rces

into th

e CA

ISO W

holesale

Market

302n

d Trienn

ial (20

15‐201

7)PG

&E

2.01 ‐ Evalua

te Storage

the Distrib

ution Grid

on

Rene

wab

les/DE

R Integration

Resource

• Project is c

urrently on‐ho

ld.

AppA-97

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

312n

d Trienn

ial (20

15‐201

7)PG

&E

2.02 ‐ Pilot D

istrib

uted

En

ergy Resou

rce

Man

agem

ent S

ystems

(DER

MS)

Rene

wab

les/DE

R Integration

Resource

•• Project is in the Bu

ild/Test p

hase.

• Co

mpleted

site accep

tance testing an

d IT build. D

ERMS is curren

tly live in th

e fie

ld• Nine da

ta interfaces develop

ed and

tested

: weather and

gen

eration forecasters, DG aggregators, A

MI and

SCA

DA sy

stem

s.

Successfully com

pleted

the DE

RMS foun

datio

n allowing the commen

cemen

t of u

se case testing.

• Be

gan fie

ld dem

onstratio

n of se

ven use cases in July

• Installed of Pha

sor M

easuremen

t Units (P

MUs) at e

xisting substatio

n an

d ne

ar th

e BE

SS and

assessed the im

pacts o

f market

participating BE

SS on op

erating cond

ition

s.• Next steps includ

e completion of use case de

mon

stratio

n, M

&V an

alysis, Final Rep

ort com

pletion an

d project closeou

t

322n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

A ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Photovoltaics (PV

)

Rene

wab

les/DE

R Integration

Resource

• Project is in the Bu

ild/Test p

hase.

• Successful com

pleted

Volt/Watt fun

ctiona

lity an

d Vo

lt/Va

r fun

ctiona

lity acceptan

ce te

sting in August a

nd Sep

tembe

r respe

ctively.

• Initial dep

loym

ent o

f the

techno

logy sh

owed

the following:

a) Customer acquisition an

d targeted

dep

loym

ent o

f DER

s is c

hallenging.

b) Smart inverter techn

ology is ab

le to

affe

ct local premise

voltage.

c) Im

plem

entatio

n of an aggregator so

lutio

n un

veiled that th

e up

time commun

ications are not with

in trad

ition

al utility

uptim

erequ

iremen

ts. H

owever, the

latency of th

e de

vices m

eets or e

xceeds th

at of P

G&E’s S

CADA

system

. • Th

e project is d

eploying Smart Inverter techn

ology on

a com

mercial fe

eder in 201

8, with

~35

% fe

eder pen

etratio

n. Throu

gh th

is the

project team expects to

better u

nderstan

d recommen

datio

ns aroun

d: sm

art inverter settin

gs, effe

cts o

f prim

ary an

d second

ary volta

ge,

bene

fits o

f a th

ird‐party m

onito

r and

con

trol platform and

cost com

parison

s of smart inverter techn

ology compa

red to trad

ition

al

utility infrastructure upgrade

s.

• Next steps includ

e completion of use case testing of sm

art inverter o

n a volta

ge con

strained

distrib

ution feed

er, M

&V an

alysis, Final

Repo

rt com

pletion an

d project closeou

t

AppA-98

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

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HA

RG

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ram

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Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

332n

d Trienn

ial (20

15‐201

7)PG

&E

2.03

B ‐ T

est S

mart Inverter

Enha

nced

Cap

abilitie

s ‐

Vehicle to Hom

e

Rene

wab

les/DE

R Integration

Resource

• Project com

pleted

in Feb

ruaray 201

8• Th

e project d

emon

strated that a bi‐d

irectiona

l EV an

d charger can su

pport critical hou

seho

ld load

s throu

gh an ou

tage. H

owever, the

project a

lso determined

that, in ad

ditio

n to th

e techno

logy not being com

mercially available, it is not cost e

ffective for customers to

adop

t. Th

is was su

pported by th

e project’s customer su

rvey re

sults which indicate th

e curren

t cost e

stim

ate is roughly 4 tim

es highe

r than an op

timal pric

e for con

sumers. The

refore, even thou

gh th

e project u

se cases were technically proven‐‐ the

y are no

t currently

feasible due

to te

chno

logy cost, lim

ited market v

alue

, and

other re

stric

tions between actors (e

.g. EV ba

ttery warranty coverage).

• Fina

l Rep

ort include

d in th

is 20

17 EPIC An

nual Rep

ort

342n

d Trienn

ial (20

15‐201

7)PG

&E

2.04 ‐ DG

Mon

itorin

g Vo

ltage Tracking

&

Rene

wab

les/DE

R Integration

Resource

•• Project com

pleted

in 201

7.• Th

is project d

emon

strated an algorith

mic process fo

r ana

lyzin

g ne

w data sources (includ

ing Sm

artM

eter™ devices and

datab

ases of

solar irrad

iance) to

predict th

e likelihoo

d that a Rule 2 volta

ge violatio

n was cau

sed by distrib

uted

solar g

eneration. Solar ene

rgy is by

nature interm

itten

t, an

d eb

bs and

surges of g

eneration can chan

ge th

e volta

ge fo

r neighbo

ring, dow

nstream customers. This

functio

nality, if integrated

into a larger grid

ana

lytics p

latform, m

ight im

prove de

cisio

n making for p

ower qua

lity en

gine

ers respo

nding

to customer issues.

• Fina

l Rep

ort include

d in th

is 20

17 EPIC An

nual Rep

ort.

352n

d Trienn

ial (20

15‐201

7)PG

&E

2.05 ‐ Inertia

Respo

nse

Emulation for D

G Im

pact

Improvem

ent

Rene

wab

les/DE

R Integration

Resource

• Project is in the De

sign/En

gine

ering ph

ase.

• NRE

L en

gaged as dem

onstratio

n site.

• Next steps In

clud

e, te

st bed

& ene

rgy storage

simulation to evaluate system

‐scale cap

abilitie

s commiss

ioning, synthetic inertia

use

and validate ap

plication scen

arios

case te

sting of ene

rgy storage, and

mod

eling an

d

AppA-99

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

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NN

UA

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EPO

RT

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NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

362n

d Trienn

ial (20

15‐201

7)PG

&E


Tran

sformer (IUT)

Rene

wab

les/DE

R Integration

Resource

• Project p

ut on ho

ld after determining the prod

uct (IUT) was not m

ature en

ough fo

r a te

chno

logy dem

onstratio

n through EP

IC.

372n

d Trienn

ial (20

15‐201

7)PG

&E

2.07 ‐ Re

al‐Tim

e Load

ing

Data fo

r Distrib

ution

Ope

ratio

ns and

Plann

ing

Grid

Mod

ernizatio

n Optim

izatio

nan

d • • Project is in the Bu

ild/Test p

hase.

• Gathe

red stakeh

olde

r inp

ut on prelim

inary prototype ap

plication de

velope

d by ven

dor.

• Tran

sitione

d vend

or m

odel into PG&E en

vironm

ent, integrated

mod

el with

real‐tim

e da

ta inpu

ts, and


e ad

dressin

g remaining issues with

mod

el inpu

t data, fu

rthe

r refining an

d validating

requ

iremen

ts fo

r future AD

MS.

continue

d to re

fine the mod

el.

the mod

el, and

deriving

382n

d Trienn

ial (20

15‐201

7)PG

&E

2.08 ‐ "Smart" M

onito

ring

and An

alysis To

ols

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

392n

d Trienn

ial (20

15‐201

7)PG

&E

2.09 ‐ Distrib

uted

Series

Impe

dance (DSI) P

hase 2

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

402n

d Trienn

ial (20

15‐201

7)PG

&E

2.10 ‐ Em

ergency

Prep

ared

ness M

odeling

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is in the Bu

ild/Test p

hase.

• De

velope

d initial prototype

of o

ptim

izatio

n mod

el and

associated visualiza

tion tool.

• Establish

ed live data interfaces to

the prototype an

d de

mon

strated the mod

el’s ability to re

commen

d the op

timize

d allocatio

n of

work resources to respon

d to emergency even

ts.


e migratio

n of th

e prototype to a se

lf‐containe

d clou

d solutio

n, con

necting the clou

d solutio

n to a re

al‐tim

e da

ta

repo

sitory, enh

ancing th

e user interface an

d its alignm

ent w

ith prede

fined

use cases and

Emergency Ope

ratio

ns Cen

ter p

rocesses, and

cond

uctin

g de

mon

stratio

n assessmen

t of the

tool during even

ts th

is up

coming storm se

ason

.

412n

d Trienn

ial (20

15‐201

7)PG

&E

2.11 ‐ New

Mob

ile

Techno

logy & Visu

aliza

tion

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

AppA-100

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

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NN

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EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

422n

d Trienn

ial (20

15‐201

7)PG

&E

2.12 ‐ New

Emergency

Man

agem

ent M

obile

Applications

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

432n

d Trienn

ial (20

15‐201

7)PG

&E

2.13 ‐ Digital

Substatio

n/Substatio

n Au

tomation

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

442n

d Trienn

ial (20

15‐201

7)PG

&E

2.14 ‐ Au

tomatically

Phasing Inform

ationMap

Grid

Mod

ernizatio

n Optim

izatio

nan


ild/Test p

hase.

• Brou

ght o

n 4 vend

ors tha

t each de

velope

d ph

ase iden

tification algorithm

s and

meter to

tran

sformer algorith

ms, develop

ed te

sting

processes a

nd began assessin

g the pe

rforman

ce of e

ach vend

or’s algorith

ms.

• Co

llected

add

ition

al data from

4 fe

eders a

nd used to fu

rthe

r refine an

d validate algorithm

s.• Next steps includ

e fin

alizing algorith

ms a

nd develop

ing a validation mod

el to

com

pare th

e fin

al re

sults of the

se various algorith

ms

452n

d Trienn

ial (20

15‐201

7)PG

&E

2.15 ‐ Synchrop

hasor

Applications fo

r Gen

erator

Dyna

mic M

odel Validation

Grid

Mod

ernizatio

n Optim

izatio

nan

d •• Project is in th

e Closeo

ut pha

se.

• Installed a fully fu

nctio

nal stand

‐alone

PMU sy

stem

at C

olusa Po

wer Gen

erating

• De

velope

d gene

rator statio

n mod

els a

nd• For the

disturba

nces cap

tured by th

e PM

Us, th

e existing mod

els w

ere im

proved

shutdo

wn.

Station du

ring a sche

duled gene

rator o

utage;

and validated

with

out req

uirin

g a gene

rator

• Next S

teps includ

e completion of fina

l rep

ort.

462n

d Trienn

ial (20

15‐201

7)PG

&E

2.16 ‐ En

hanced

Synchrop

hasor A

nalytics

Applications

&

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

472n

d Trienn

ial (20

15‐201

7)PG

&E

2.17 ‐ Geo

magne

tic

Disturba

nce (GMD)

Evalua

tion

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

482n

d Trienn

ial (20

15‐201

7)PG

&E

2.18 ‐ Optical In

strumen

t Tran

sformers a

nd Sen

sors

Protectio

n an

d Co

ntrol

for Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

System

s

AppA-101

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

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(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

492n

d Trienn

ial (20

15‐201

7)PG

&E

2.19 ‐ En

able Distrib

uted

De

man

d‐Side

Strategies &

Techno

logies

Custom

er Service

Enab

lemen

tan

d • • • • • • • • • •

Project com

pleted

in Feb

ruary 20

18De

mon

stratio

n installatio

n complete, field de

mon

stratio

n acceptan

ce te

sting complete

Use Case testing complete

Project K

ey Findings:

Curren

t ven

dor p

latforms for con

trolling custom

er‐site

d DE

Rs are not re

ady for u

tility

ope

ratio

nsCo

mmun

ications to

devices are not com

parable to trad

ition

al utility

com

mun

ications

Latency is compa

rable to current utility

SCA

DAAg

gregated

customer storage is effective for p

remise

load drop.

Implem

entatio

n of com

man

d prioritiza

tion wou

ld be requ

ired for future multip

le‐use app

lications.

Fina

l Rep

ort include

d in th

is 20

17 EPIC An

nual Rep

ort

502n

d Trienn

ial (20

15‐201

7)PG

&E

2.20 ‐ Re

al‐Tim

e Usage Feedb

ack

Custom

ers

Energy

to

Custom

er Service

Enab

lemen

tan

d • Project is c

urrently on‐ho

ld.

512n

d Trienn

ial (20

15‐201

7)PG

&E

2.21 ‐ Ho

me Area Network

(HAN

) for Com

mercial

Custom

ers

Custom

er Service

Enab

lemen

tan

d • Project com

pleted

in Feb

ruary 20

18• Co

mpleted

executio

n of field testing, field surveys, and

data to com

pile

• Iden

tified ad

optio

n, integration, and

utiliza

tion ba

rriers associated with

de

vices.

results and

find

ings.

mass d

eploym

ent o

f real tim

e Zigbee data through HA

N

• Fina

l Rep

ort include

d in 201

7 EP

IC Ann

ual Rep

ort

522n

d Trienn

ial (20

15‐201

7)PG

&E

2.22 ‐ De

man

d Re

duction

through Targeted

Data

Analytics

Custom

er Service

Enab

lemen

tan


ild/Test p

hase.

• Integrated

Ene

rgy Efficen

cy (E

E) Loa

d Shap

es into m

odel

• Co

mpleted

work on

Customer Prope

nsity

mod

el• Incorporated

E3 en

ergy storage mod

el and

tested

and

validated

DR mod

el• Fina

lized

all DE

R load sh

apes, d

ispatch, customer se

lection crite

ria• Co

mpleted

fron

t end

develop

men

t with

work on

optim

izatio

n functio

n• Next steps includ

e op

timiza

tion im

provem

ent, Trad

ition

al W

ires A

lternatives

completion an

d project closeou

t.to be ad

ded to to

ol optim

izatio

n, Final Rep

ort

AppA-102

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

532n

d Trienn

ial (20

15‐201

7)PG

&E


man

d Ap

proa

ches In

to Utility

Plan

ning

Side

Customer Service

Enab

lemen

tan

d • Project com

pleted

in 201

7.• Th

is project successfully develop

ed and

dem

onstrated the integration of a broad

er ra

nge of customer‐side techno

logies and

Distrib

uted

Ene

rgy Re

sources (DE

R) app

roache

s into the utility plann

ing process.

• Th

e project served as a necessary and

ena

bling precursor to the fulfillm

ent o

f Pub

lic Utility

Cod

e 769

, which re

quire

s transpa

rent,

consisten

t and

more accurate m

etho

ds to

cost‐effectively integrate DE

Rs into th

e distrib

ution plan

ning process.

• Th

is project d

elivered

new

load sh

ape profiles, enh

anced load fo

recasting tool and

overall an

alytical process th

at allows P

G&E to

more accurately and

con

sistently integrate DE

R im

pact to

the distrib

ution system

load profile.

• With

these en

hancem

ents, PG&E can more effectively assess th

e im

pact of D

ER growth on the tim

ing an

d ne

ed fo

r future distrib

ution

and tran

smiss

ion system

upgrade

• Fina

l Rep

ort include

d in th

is 20

17 EPIC An

nual Rep

ort.

542n

d Trienn

ial (20

15‐201

7)PG

&E

2.24 ‐ Ap

pliance Level Bill

Disaggregatio

n for N

on‐

Resid

entia

l Customers

Custom

er Service

Enab

lemen

tan

d • Project is c

urrently on‐ho

ld.

552n

d Trienn

ial (20

15‐201

7)PG

&E

2.25 ‐ En

hanced

Smart

Commun

ications

Grid

Cross‐Cu

tting/Foun

datio

nal

• Project is c

urrently on‐ho

ld.

562n

d Trienn

ial (20

15‐201

7)PG

&E

2.26 ‐ Cu

stom

er &

Distrib

ution Au

tomation

Ope

n Archite

cture De

vices

Cross‐Cu

tting/Foun

datio

nal

• Project in De

sign/Bu

ild pha

se• Establish

ed use‐cases fo

r AMI techn

ology de

mon

stratio

n includ

ing –

• Th

e ab

ility to

com

mun

icate, con

trol, transmit da

ta, and

upgrade

firm

ware on

to FLISR overhead an

d un

dergroun

d de

vices o

ver the

ne

twork

• Direct acquisition an

d control telem

etry so

lutio

n with

enh

anced security an

d cybe

r isolatio

n for m

edium‐size

d en

ergy gen

eration

projects

•Th

e ab

ility to

com

mun

icate with

RFID eq

uipm

ent o

ver the

network.

• Next S

teps includ

e execution of use‐cases in lab an

d/or field en

vironm

ents.

572n

d Trienn

ial (20

15‐201

7)PG

&E

2.27 ‐ Next G

eneration

Integrated

Smart G

rid

Network Man

agem

ent

Cross‐Cu

tting/Foun

datio

nal

• Project is in the Closeo

ut pha

se.

• De

velope

d a de

mon

stratio

n grad

e man

agem

ent p

latform th

at su

ccessfully iden

tified inventory, con

figuration, and

perform

ance data

for a

ll three AM

I networks includ

ing bo

th networking elemen

ts and

metering en

dpoints.

• Th

e project learned

the complexity

of a

dding functio

ns neede

d such as a

ddition

al Head‐En

d Network Man

agem

ent fun

ctions,

integration with

GIS layers (i.e. d

ata sources like CC

&B, M

DMS), and

integration with

various PG&E ticketin

g system

s (Re

med

y, FAS

). Ba

sed on

this complexity

, an en

terprise man

agem

ent system will be ne

eded

to sc

ale the functio

ns dem

onstrated through this project.

• Next S

teps includ

e completion of close‐out re

port.

582n

d Trienn

ial (20

15‐201

7)PG

&E

2.28 ‐ Sm

art G

rid

Commun

ications

Mon

itorin

gPath

Cross‐Cu

tting/Foun

datio

nal

• Project com

pleted

in Feb

ruary 20

18

• De

velope

d a ne

twork configuration plan th

at wou

ld ena

ble PG

&E to gathe

r relevan

t externa

l data sources throu

gh a se

cure VPN

tunn

el onto PG

&E’s n

etwork.

• Iden

tified minim

um data po

ints and

sources o

f this d

ata to pursue the techno

logy dem

onstratio

n.• Th

is project h

as been sunset early based

on fin

dings tha

t the

data requ

ired for the

algorith

m to

be effective was not available (neithe r

via internal nor externa

l sou

rces).

• Fina

l Rep

ort include

d in 201

7 EP

IC Ann

ual Rep

ort

AppA-103

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv. 2

017 Status Upd

ate

592n

d Trienn

ial (20

15‐201

7)PG

&E

2.29 ‐ Mob

ile

Applications

Meter

Cross‐Cu

tting/Foun

datio

nal

• • Project is in the Bu

ild/Test p

hase.

• Fina

lized

accep

tance testing proced

ure for N

ext G

en M

eters (NGM)

• Co

nducted functio

nal and

accep

tance testing on

alpha and

beta NGM prototype

s.• De

mon

strated mob

ile app

lication of NGM prototype

at P

G&E

• Next S

teps includ

e refin

ing integration of accelerom

eter into th

e NGM, d

esigning, implem

entin

g an

d testing AN

SI Stand

ards C12

.19

and C1

2.22

and

head en

d ap

plication into NGM, and

integrating 90

0 MHz

network card te

chno

logy into th

e NGM to

leverage th

e existing AM

I network for com

mun

ication

602n

d Trienn

ial (20

15‐201

7)PG

&E


s to

Participate in In

dustry‐W

ide

RD&D Programs

Grid

Mod

ernizatio

n Optim

izatio

nan

d • Project is c

urrently on‐ho

ld.

612n

d Trienn

ial (20

15‐201

7)PG

&E

2.31 ‐ Ag

gregated

Beh

ind‐


arket

Retail Optim

izatio

n/

Rene

wab

les/DE

R Integration

Resource

• Form

ally W

ithdraw

n by PG&E on

07/31

/201

7 via PG

&E Co

mmen

ts on Draft R

esolution E‐48

63

AppA-104

APP

END

IX A

ELEC

TRIC

PR

OG

RA

M IN

VEST

MEN

T C

HA

RG

E20

17 A

NN

UA

L R

EPO

RT

(CO

NTI

NU

ED)

Row #

Prog

ram

Administrator

Project N

ame

Project T

ype

2017 Upd

ate

AB

CD

ADFor

Repo

rt

DOC

i. Investmen

t Plan Pe

riod

Project N

ame

xv.2

017 Status Upd

ate

622n

d Trienn

ial (20

15‐201

7)PG

&E

2.32 ‐ Electric

Man

agem

ent

Electrificatio

n

Load

for R

idesha

ring Re

newab

les/DE

R Integration

Resource

•De

ferred

to a fu

ture investmen

t plan by CPU

C. Resolution E‐48

63. 08/10

/201

7

632n

d Trienn

ial (20

15‐201

7)PG

&E

2.33 ‐ Service

Iden

tification

Mom

entary O

Inform

ation

Issue

Leveraging

utage

Grid

Mod

ernizatio

n Optim

izatio

nan

d •De

ferred

to a fu

ture investmen

t plan by CPU

C. Resolution E‐48

63. 08/10

/201

7

642n

d Trienn

ial (20

15‐201

7)PG

&E

2.34 ‐ Pred

ictiv

e Risk

Iden

tification with

Rad

io

Freq

uency (RF) Add

ed to

Sensors

Line

Grid

Mod

ernizatio

n Optim

izatio

nan

d •Project is in the Plan

/Ana

lyze pha

se.

• Co

nducted prelim

inary assessmen

t of


e assessing technical

and testing combine

d sensor so

llutio

n, in

dustry cap

abilitie

sfeasibility and

poten

tial sen

sor ran

ge to

validate

project closeou

t and

project fina

l rep

ort.

oppo

rtun

ity fo

r business b

enefits, d

evelop

ing

652n

d Trienn

ial (20

15‐201

7)PG

&E

2.35 ‐ Ca

ll Ce

nter

Optim

izatio

nStaffin

g Grid

Mod

ernizatio

n Optim

izatio

nan

d •Re

jected

by CP

UC. Resolution E‐48

63. 08/10

/201

7

662n

d Trienn

ial (20

15‐201

7)PG

&E

2.36 ‐

Tool

Dyna

mic Rate De

sign

Custom

er Service

Enab

lemen

tan

d •Project is in the Plan

/Ana

lyze pha

se• Next steps includ

e creatin

g technical architecture specificatio

ns, d

evelop

data ba

ses, develop

test

engine

, develop

and

build API, final verificatio

n testing, project closeou

t and

project fina

l rep

ort.

plan

, build datab

ase an

d platform


previou

s ann

ual rep

ort

AppA-105

BEFORE THE PUBLIC UTILITIES COMMISSION

OF THE STATE OF CALIFORNIA

Application of the California Energy

Commission for Approval of Electric Program

Investment Charge Proposed 2015 through

2017 Triennial Investment Plan.

A.14-04-034

(Filed April 29, 2014)

And Related Matters.

A.14-05-003

A.14-05-004

A.14-05-005

NOTICE OF AVAILABILITY (IN LIEU) OF

THE 2017 ANNUAL ELECTRIC PROGRAM

INVESTMENT CHARGE REPORT OF PACIFIC GAS

AND ELECTRIC COMPANY (U 39 E)

Dated: February 28, 2018

CHRISTOPHER J. WARNER

Pacific Gas and Electric Company

77 Beale Street, B30A

San Francisco, CA 94105

Telephone: (415) 973-6695

Facsimile: (415) 973-5520

E-Mail: [email protected]

Attorney for


mailto:[email protected]

1

BEFORE THE PUBLIC UTILITIES COMMISSION

OF THE STATE OF CALIFORNIA

Application of the California Energy

Commission for Approval of Electric Program

Investment Charge Proposed 2015 through

2017 Triennial Investment Plan.

______________________________________

And Related Matters.

A.14-04-034

(Filed April 29, 2014)

A.14-05-003

A.14-05-004

A.14-05-005

NOTICE OF AVAILABILITY (IN LIEU) OF

THE 2017 ANNUAL ELECTRIC PROGRAM

INVESTMENT CHARGE REPORT OF PACIFIC GAS

AND ELECTRIC COMPANY (U 39 E)

TO ALL PARTIES IN A.14-04-034, et al.

PLEASE TAKE NOTICE THAT on February 28, 2018, Pacific Gas and Electric

Company (PG&E) served its 2017 Annual Electric Program Investment Charge Report. Due to

the large file size, PG&E hereby provides this Notice of Availability. The Report consists of the

Pleading, Attachment A- 2017 Annual Report, Attachment B- 2017 Annual Report Appendix A

and Attachment C- Appendices B-H which are available on PG&E’s website at the link

provided:.

1) Search for Public Case Documents: https://pgera.azurewebsites.net/Regulation/search

2) Select “EPIC Investment Plan 2018-20” from the case dropdown menu;

3) Select “PGE” from the party dropdown menu;

4) Input the date from “02/28/18” to “02/28/18”; and

5) Click Search.

PG&E will, upon request, provide a hard copy of the above-described report. PG&E asks

that requests be submitted in writing by e-mail or facsimile transmission to:

https://pgera.azurewebsites.net/Regulation/search

2

Helen Jorgenson

PG&E’s Law Department

77 Beale Street, Mail Code B30A


Telephone: 415.973.6477

Facsimile: 415.973.5520

E-mail: [email protected]

Dated: February 28, 2018

Respectfully Submitted,


By: /s/ Christopher J. Warner


Pacific Gas and Electric Company

77 Beale Street, B30A


Telephone: (415) 973-6695

Facsimile: (415) 973-5520

E-Mail: [email protected]

Attorney for


