(U 338-E) 2018 General Rate Case A Workpapers. T&D- Grid Technology SCE-02 Volume 11

Transcription

1 (U 338-E) 2018 General Rate Case A Workpapers T&D- Grid Technology SCE-02 Volume 11 September 2016

2 SUMMARY OF TESTIMONY A. Content and Organization of Testimony This volume of testimony is organized into O&M and capital activities. The O&M activities cover the costs of evaluating new technologies and deploying and operating the Advanced Outage Detection and Analytics capital project. The capital activities are divided into three general areas. 1. Advanced Technology Laboratories: SCE has three laboratory facilities (Fenwick, Pomona, and Equipment Demonstration and Evaluation Facility (EDEF)), which provide long-term, comprehensive, and dynamic testing environments. Combined, these labs support investigating, modeling, validating, and piloting new and emerging technologies prior to deploying them on the grid. SCE s efforts in the labs help prudently integrate new technologies on our system to the benefit of our customers. 2. Pilots: Technologies such as energy storage systems are evolving. Piloting helps determine the technology s ability to perform under actual conditions on SCE s grid and helps us efficiently and safely integrate it onto the grid. Pilots also help guide us in making prudent choices in how and when we invest in more widespread deployment of advanced technologies. 3. Grid Integration activities: These activities encompass grid solutions that use technologies we have previously tested, evaluated and piloted, and are now deploying onto the grid. 1. Summary of O&M and Capital Request Table I-1 and Table I-2 below summarize the O&M and capital activities discussed in this volume along with the associated costs. Table I-1 Grid Technology O&M Activities (Total Company Constant 2015 $000) Activity 2018 Forecast Grid Advancement $15,915 Advanced Outage Detection & Analytics Project $590 Total $16,505 1

3 2 Workpaper Southern California Edison / 2018 GRC Table I-2 Grid Technology Capital Activities (CPUC-Jurisdictional Nominal $000) Description DVVC 2,571 2,651 4,414 4,558 4,705 Consrvtn Voltage Reg 1,605 2, Advanced Technology 9,575 8,676 5,928 8,122 11,508 Energy Storage Pilot Program 8,448 14,518 22,499 15,317 7,801 Advanced Outage Detection & Analytics ,144 14,711 8,392 Total $22,198 $28,699 $52,985 $42,708 $32,406 2

4 DECISION A. Compliance Requirements In D , the Commission adopted the majority of SCE s request for Lab upgrades, but rejected a portion of SCE s funding request for the Westminster lab. The Commission rejected all of the funding for the EDEF, because the Commission found that SCE had not demonstrated that the problems it would address are unique to SCE and that other most cost-effective options do not exist. 1 SCE addresses these concerns in Section V.1.c below, and shows that its labs are addressing SCEspecific issues in a prudent manner. 1 D ( 2015 GRC Decision ), p

5 4 Workpaper Southern California Edison / 2018 GRC 1 B. Comparison of Authorized 2015 to Recorded Figure II-1 Grid Technology GRC Authorized Variance Summary 2015 O&M (Total Company Constant 2015 $Millions) Grid Technology recorded $15.9 million in O&M expenses in 2015, which was $0.5 million higher than the authorized amount of $15.4 million. Based on the current mix of programs, Grid Technology was able to spend within 3% of its authorized amount. 2 Refer to WP SCE-02 Vol. 11, p. 1 (O&M Authorized vs. Recorded). 4

6 5 Figure II-2 Grid Technology GRC Authorized Variance Summary 2015 Capital (CPUC-Jurisdictional Nominal $Millions) Grid Technology recorded $12 million in Capital expenses in This is $2 million more than the $10 million authorized in SCE s 2015 GRC. The increased spending was driven primarily by the EDEF. This project is discussed in greater detail in Section V.1.c below. 3 Refer to WP SCE-02 Vol. 11, p. 2 (Capital Authorized vs. Recorded). 5

7 6 Workpaper Southern California Edison / 2018 GRC DESCRIPTION OF ORGANIZATION AND BACKGROUND A. Overview of Activities Federal and state policies are continuing to change the way electricity is produced and consumed. Customers are accelerating the adoption of technologies such as photovoltaic (PV), energy storage, and electric vehicles. Supporting the public policies and meeting our customers needs have profoundly affected how the utility must now build and operate the grid. These policies are causing SCE to advance the way it operates the grid to provide clean, safe, reliable and affordable power to its customers. Under California s recently expanded Renewable Portfolio Standard (RPS), SCE must purchase 50 percent of its energy from renewable resources by Because of intermittent sun and wind conditions, renewable power can fluctuate significantly. These power quality fluctuations, if left unmitigated, can cause serious problems to electric distribution equipment, and even adversely affect customers electrical devices. The increasing number of distributed energy resources (DERs) on customer homes and businesses has increased the complexity of grid operations, and these new configurations present challenges and opportunities for the distribution grid. 4 Under the Commission s energy storage mandate, ever-increasing amounts of energy storage are expected to connect to the grid. However, the storage systems (battery cells, the balance-of-plant electrical equipment and firmware, which manages the performance of batteries) are still evolving. These technologies need to be further tested and evaluated. We need to pilot the systems on the distribution grid to determine how these systems can provide support as the operating environment changes and potentially increase the value of DERs by mitigating any negative impacts. Such piloting helps SCE safely and reliably integrate energy storage systems onto the grid. The proliferation of electric vehicles can overload distribution circuits, and if not managed properly, will lead to grid instability or outages. SCE has approximately 60,000 light-duty (residential and fleet) electric vehicles connecting to the grid. An increasing number of commercial customers such as United Postal Services (UPS) are also adopting electric transportation for fleet operations. Transit agencies such as Foothill and Antelope Valley are planning to expand their current fleet of buses to be 4 Refer to SCE-01, and SCE-02, Vol. 3. 6

8 all-electric. As more heavy-duty vehicles electrify, demand for high-powered fast-charging will increase. SCE is continuing to evaluate the system impact of such charging, but also investigating ways to reasonably charge the vehicles in a way that more efficiently utilizes the infrastructure. SCE s Advanced Technology Division provides technology solutions to serve our customers changing needs and comply with many ambitious federal and state energy policy targets while maintaining grid safety and reliability. New technologies must be identified, assessed for their maturity and performance, and tested for their intended purposes. These new technology solutions must be verified and validated before SCE makes large-scale investment and deployment decisions, either to deploy or prepare its grid and operations to incorporate such technologies. After SCE applies its rigorous and robust process, the new technologies can be safely and predictably integrated into SCE s grid. Since 2009, SCE has taken these types of measured and prudent steps to identify and assess promising technologies, test their performance in the laboratories, and demonstrate and pilot them in a real, integrated grid environment prior to their being deployed or otherwise connected to the grid. As public policy goals and technological capabilities continue to evolve, these efforts continue to increase in importance. Our work here helps SCE comply with policy requirements, mitigate operational challenges, and enable customer choices. The Grid Technology request I am sponsoring provides a reasonable level of resources and activities needed to support SCE continuing to provide safe, affordable, reliable, and clean electricity to its customers. 7

9 8 Workpaper Southern California Edison / 2018 GRC O&M A. Grid Technology Expenses (Portions of GRC Account and ) Grid Technology activities include: Using technology to perform advanced systems studies and develop models to better understand grid operations in an ever-changing environment. This is especially important in light of the increasing penetration of renewable and distributed energy resources, which have corresponding impacts on operations; Operating an integrated set of laboratory capabilities to develop operational and technology solutions, and safely test and evaluate those solutions prior to deploying them in the field; Supporting the development of industry standards that promote equipment interoperability, vendor diversity, and prudent long-term asset deployment strategies; and Supporting the Distribution Resources Plan, which requires the Utilities to perform five demonstration projects, 5 as well as supporting the Commission s Energy Storage Initiative. The Energy Storage Initiative requires that SCE procure 580 MW by 2020 (and online by 2024). 6 SCE s distribution grid is becoming more complex, with new challenges, but also with new opportunities to integrate clean, distributed generation resources for SCE s customers. SCE s Grid Technology efforts play a vital role in testing and evaluating these promising technologies and testing them in a laboratory setting. Grid Technology prioritizes its program with input from other SCE operating groups and through extensive external engagement with other entities, such as U.S. Department of Energy (DOE) National Labs, other utilities, industry research organizations, academia, and the vendor community. For each effort, we determine whether SCE s role will be to lead, participate in, or monitor testing activities. Typically, SCE leads on high-priority projects where it has the expertise and facilities capable of testing the technologies against SCE-specific operating protocols (e.g., the equipment and evaluation facility at SCE s facility in Westminster, California). 5 R D

10 SCE participates with industry groups and agencies to evaluate new technologies and mitigate expenses and risks. As an example, SCE collaborated with the South Coast Air Quality Management District (SCAQMD) on the Zero Emission Cargo Movement, or e-highway project, to demonstrate electrified drayage 7 trucks that can operate on the road with electric drive connected to an overhead power line. Finally, SCE monitors emerging technology testing by other parties where SCE does not possess adequate resources, seeks to avoid costs from potentially high risks, and/or can leverage the efforts of third parties. As an example, SCE monitors compressed air energy storage technology development work by others such as DOE, the Electric Power Research Institute (EPRI), and national labs on compressed air energy storage technologies and flow battery storage technologies. Grid Technology activities for transmission systems are charged to GRC Account Work performed for the distribution system is charged to GRC Account Since the activities are similar, and the expenses recorded in and in any particular year can vary based on the specific projects, SCE is combining its discussion of historical expense analysis and forecasts for these two accounts. 7 The transport of goods over a very short distance during a single work shift. 9

11 10 Workpaper Southern California Edison / 2018 GRC 1 1. Cost Forecast Table IV-3 Grid Technology Expenses GRC Accounts and Portion of Recorded and Adjusted /Forecast (Constant 2015 $000) Recorded Forecast Labor $2,938 $2,539 $2,302 $1,945 $1,610 $1,610 $1,610 $1,610 Non-Labor $2,098 $493 $480 $769 $988 $988 $988 $988 Subtotal $5,036 $3,033 $2,782 $2,714 $2,598 $2,598 $2,598 $2, Labor $7,705 $7,553 $6,928 $7,206 $8,155 $8,155 $8,155 $8,155 Non-Labor $6,069 $4,722 $5,062 $5,397 $5,162 $5,162 $5,162 $5,162 Subtotal $13,775 $12,275 $11,990 $12,603 $13,317 $13,317 $13,317 $13,317 Total $18,811 $15,308 $14,772 $15,317 $15,915 $15,915 $15,915 $15,915 Labor $10,643 $10,093 $9,230 $9,151 $9,764 $9,764 $9,764 $9,764 Non-Labor $8,168 $5,215 $5,542 $6,166 $6,151 $6,151 $6,151 $6,151 Ratio of Labor to Total 57% 66% 62% 60% 61% 61% 61% 61% Basis of Forecast: Last Year Recorded Costs Basis of Labor/Non-Labor Split: Last Year Labor/Non-Labor Ratio The labor expenses for these activities include payroll for engineers and management working on the activities described above. This work is supplemented by contract personnel when the efforts are of shorter duration, or when unique subject expertise is needed. Expenses for contract personnel are recorded as non-labor. Allocated overheads, small tools and equipment, and purchases of technologies tested are also recorded as non-labor expenses. From 2011 to 2012, labor costs decreased by $550,000 and non-labor costs by $2.953 million. The 2012 labor decrease was primarily due to engineering personnel completing their 8 Refer to WP SCE-02 Vol. 11, pp (GRC Account ) and pp (GRC Account ). 10

12 evaluation and testing assignments and charging to the next phase of capital deployment projects. 9 The non-labor expenses decreased because we relied less and less on consulting and contractor services for ongoing Advanced Technology activities. 10 The completion of the Westminster Laboratories and Large Energy Storage Test Apparatus also allowed SCE personnel to handle a variety of technology testing and evaluation activities and advanced system studies in-house. From 2012 to 2013, labor costs decreased by $863,000 and non-labor costs increased by $327,000. The labor decrease was primarily due to a reorganization where regulatory policy and transportation electrification policy employees moved into the Regulatory Affairs organization. The non-labor increase was primarily due to support for the Substation Automation Hybrid-Solutions effort and support of an electric vehicle smart charging pilot. From 2013 to 2014, labor costs decreased by $79,000 and non-labor increased costs by $624,000. The non-labor increase was primarily due to consultant charges associated with organizational, communications and management strategy improvement efforts. From 2014 to 2015, labor costs increased by $613,000 and non-labor costs decreased by $15,000. The labor increase was primarily due to the hiring of staff to support energy storage procurement activities. 11 Since its inception in 2009, SCE s Grid Technology has continued to mature, which has allowed it to maintain and in some instances increase work levels, while limiting cost increases. As such, SCE proposes to use the last recorded year as the basis for its test year request for both the Transmission and Distribution Grid Technology. This results in a 2018 forecast of $ million, which is the same amount as the $ million recorded in B. Advanced Outage Detection and Analytics Program Enhancements to SCE s Outage Management System which leverages SmartConnect meters can significantly improve the current detection, identification, and response to customer power outages. As discussed later in (reference) certain O&M costs will be incurred by this project. We include the 9 The Centralized Remedial Action System and Phasor Measurement & Wide Areas Situational Awareness System projects moved from testing and evaluation phase to the implementation phase, thus incurring less O&M expenses. 10 SCE did, however, continue to utilize these resources for its American Reinvestment and Recovery projects. 11 Commission Decision established an energy storage target of 1,325 megawatts for Pacific Gas and Electric Company, Southern California Edison, and San Diego Gas & Electric by 2020, with installations required no later than the end of

13 12 Workpaper Southern California Edison / 2018 GRC estimates here to present a complete set of O&M for this volume. The O&M cost estimate for the system enhancement uses standard IT estimating practices of 4% of total capital cost, which is approximately $1.3 million. There is a one-time O&M cost for drafting the necessary request for information, request for proposals, and purchase orders for the firmware enhancement, bellwether management, and Outage Management System Capability enhancements. The normalized cost over for the O&M labor and non-labor for all three enhancements is $590,000 per year. 1. Cost Forecast Figure IV-3 Advanced Outage Detection and Analytics Project Portion GRC Account Recorded and Adjusted /Forecast (Constant 2015 $000) Recorded Forecast Labor $ $ $ $ $ $ $ $75 $160 $650 Non-Labor $ $ $ $ $ $ $ $75 $160 $650 Total $ $ $ $ $ $ $ $150 $320 $1,300 Ratio of Labor to Total N/A N/A N/A N/A N/A N/A N/A 50% 50% 50% Basis of Forecast: Itemized Forecast (Normalized by using Average Total Cost) Basis of Labor/Non-Labor Split: Itemized Forecast Normalized Test Year Forecast 2018 Labor $295 Non-Labor $295 Total $ Refer to WP SCE-02 Vol. 11, pp

14 CAPITAL EPENDITURES SCE faces increasing operating complexities, and must properly test and evaluate emerging technologies prior to deploying potential improvements across SCE s 50,000-square mile service territory. The Commission authorized funding for SCE to develop laboratory capabilities, providing the base capabilities needed to identify issues and test potential solutions. Given the increasing operating complexity, it is prudent for SCE to continue testing and integrating new technology solutions, which is primarily accomplished through the Advanced Technology labs. To identify and determine which technological solutions will help advance the power grid with clean resources, while maintaining safety and reliability, SCE will continue to: Evaluate the business need for new technologies; Test the technology components in the laboratories to determine whether they can withstand the requirements of grid operations; Determine the broader equipment capabilities in a controlled environment without affecting service to our customers; Pilot the combined systems on SCE s grid to determine their ability to perform under actual conditions; and Deploy technological integration solutions. SCE s capital request for Grid Technology will provide the funding to continue building on existing capabilities, keep current on evolving technologies, and upgrade capabilities in a reasonable manner to meet the increasing complexity of operating requirements, driven by federal and state energy policy mandates. The areas of capital expenditures are shown in the Table below: 1. Advanced Technology Laboratory Facilities a. Fenwick Labs b. Pomona Lab c. Equipment Demonstration and Evaluation Facility 2. Energy Storage Pilots a. Distributed Energy Storage Integration Pilot Program 3. Technology Integration a. Distribution Volt VAR Control b. Advanced Outage Detection and Analytics 13

15 14 Workpaper Southern California Edison / 2018 GRC A. Advanced Technology Laboratories Advanced Technology (AT) labs allow us to safely evaluate, test, and pilot new and emerging technologies that support SCE in complying with public policies such as modernizing the grid, providing clean energy, enabling customer choice, and integrating distributed resources. 13 The labs also provide a means to test newer versions of existing technologies to support increased operating capabilities when replacing equipment that has reached the end of its lifecycle. SCE maintains and operates AT laboratories at three locations: the Fenwick Laboratories 14 in Westminster, CA; Pomona Laboratory, 15 in Pomona, CA; and the EDEF, located in Westminster, CA. The Fenwick labs support technology evaluation, proof-of-concept validations, and predeployment testing. This testing includes evaluating smart grid communications and cyber-security hardware, software, and systems. Our work also examines interconnecting and testing next generation substation communications, automation, and protection equipment. Our Pomona lab tests and evaluates alternative fuel and electric vehicles, fleet vocational equipment (auxiliary support equipment our utility crews utilize once deployed to a jobsite, such as gas/diesel generators, hydraulic tools, bucketlifts/cranes and electric power tools), and electric charging infrastructure. The Pomona lab also tests and evaluates battery storage components and their integration into grid-ready energy storage systems. EDEF performs evaluations of largely unproven emerging technologies in a high-voltage grid environment, and helps address immediate operational concerns, such as integrating intelligent sensors, communication devices, solar inverters, and energy storage See Overview of Activities section above for further details regarding energy policies integrating distributed resources. 14 Formerly known as the Westminster Labs. 15 Formerly known as the Electric Vehicle Technical Center (EVTC), which has been continuously operated by SCE since The name change is due to the expansion of testing in the field of energy storage and electric transportation. The EVTC is approved by the U.S. Department of Energy to evaluate electric vehicle baseline performance and fleet operations. As a result of the EVTC s prominence in the industry and the importance of its work, President Obama made an extended visit to the facility in Converts the variable direct current (DC) output of a photovoltaic (PV) solar panel into a utility frequency alternating current (AC) that can be fed into the grid. 14

16 15 Figure V-4 Advanced Technology Recorded/ Forecast Portion of WBS Element CET-OT-OT-AT 17 (CPUC-Jurisdictional Constant 2015 and Nominal $000) Fenwick Labs Upgrades a) Capital Forecast Table V-4 Fenwick Labs Upgrades Forecast (Nominal $000) Capital Expenditures (Nominal $000) Project No CET-OT-OT-AT $4,274 $4,693 $4,195 $6,258 $9,556 $28, b) Project Description The Advanced Technology Fenwick Laboratory Facility (Fenwick Labs) enables our engineers to safely evaluate and test emerging technologies, in a dynamic and fully integrated grid environment. The Fenwick Labs are composed of eight labs, which were constructed in 2010 and 17 Refer to WP SCE-02 Vol. 11, pp Refer to CET-OT-OT-AT and CET-OT-OT-AT

17 16 Workpaper Southern California Edison / 2018 GRC became fully operational in The following provides the name and a brief description of each of the labs: Situational Awareness Lab Allows SCE to monitor the status of the electric grid and display test data from adjacent labs. Utilizing a scalable video wall, this facility is also able to analyze historic outage data using proprietary system modeling tools. Communications and Computing Lab Provides a platform to test and evaluate grid communications and cyber security hardware, software and systems. Understanding the properties of high-speed, low latency, and wireless communications networks is critical to developing a secure, digitally networked grid. Power Systems Lab Utilizing real-time power systems simulators allows SCE to perform closed loop testing of protection and control equipment and power system studies. These studies are conducted to understand the impact of large scale renewable integration, as well as develop more sophisticated wide area monitoring, protection and control capabilities for the electric grid. Distributed Energy Resources Lab Inverter based generators and loads, such as residential solar panels, batteries, and air conditioners, are tested and evaluated in SCE s Distributed Energy Resources Lab. Understanding the behavior of these devices during grid faults and voltage and frequency transients will help SCE continue to maintain a reliable distribution system. Substation Automation Lab Designed for interconnecting and testing next generation substation communications, automation, and protection equipment. Incorporating these secure and open standards based systems will help SCE continue to maintain smarter, safer, reliable, and cost-effective substations. Distribution Automation Lab Evaluates the performance of advanced field devices to develop an integrated, scalable and fully automated distribution system. These efforts will help SCE safely and reliably manage the integration of distributed energy resources such as residential solar panels and PEVs. Grid Edge Solutions Lab Helps provide customers with advanced tools and resources that will enable informed and responsible energy use. The lab evaluates third party smart energy devices to help ensure compatibility with Edison SmartConnect meters and to support SCE s rate programs and services. 16

18 Garage of the Future Lab Demonstrates and evaluates the synergy of various technologies including distributed energy storage, renewable energy resources, PEV charging infrastructure and Edison SmartConnect meter communication. The Commission approved the construction and operations of the Fenwick Labs in the 2012 GRC. SCE requested subsequent expansion of the labs in its 2015 GRC, most of which the Commission adopted. 18 Beginning in 2017, the Fenwick Labs site will expand upon its existing capabilities, adding two additional labs (the Distribution Grid Analytics Lab and the Controls Lab) and a Technology Transfer Center supporting grid modernization and SCE s DRP. The Distribution Grid Analytics Lab models and analyzes circuit and customer characteristics to determine mitigation strategies for high penetration of Distributed Energy Resources. The Lab s equipment is divided into two major areas: Systems to test Smart Inverter equipment; and system models and time series data for renewable integration analytics. The Smart Inverter test equipment includes a distribution grid simulator and a solar PV simulator. The Smart Inverter is essentially connected between these two simulators to provide a test bed to analyze the operating characteristics of the inverter. The renewable integration analytics systems focus on maintaining accurate and detailed circuit, demand, and resource models. This analytic environment requires managing large time series data sets utilizing database systems and analytical tools. The Controls Lab focuses on determining the control strategies to implement those mitigation identified by the Distribution Grid Analytics Lab. These control strategies are tested and hardware control systems are evaluated against a set of scenarios to determine their effectiveness in managing and controlling the DERs. The simulation tools in the Controls Lab require similar accurate and detailed models, but these models need to operate on a larger system model to determine optimization opportunities across a particular region of the distribution grid. These systems are generally referred to as real-time digital simulators and are directly connected to hardware control systems. This hardware-in-the-loop is beneficial in testing critical control systems in a simulated lab environment ahead of integrating these systems into actual operating systems. The Technology Transfer Center provides a hands-on environment for engineers, field employees, and operators to become familiar with future, potentially deployable tools and 18 See D , p

19 18 Workpaper Southern California Edison / 2018 GRC equipment. This Center is flexible enough to feature technologies and learnings from any of SCE s laboratories and also provides a means to host technology transfer opportunities with the DOE, EPRI, and other utilities. As noted above, SCE s role will be to lead, participate in, or monitor testing activities. In addition to providing the hands-on environment for SCE-led efforts, this Technology Transfer Center provides a means to inexpensively and effectively convey the learnings from other entities, where SCE plays more of a participant or monitoring role. While each lab has a testing and evaluation element, the labs are interconnected to allow testing across the entire electric system supply chain generation, transmission, distribution, and behind-the-meter devices. The Fenwick Labs continue to support technology evaluation, proof-ofconcept validations and pre-deployment testing. This GRC request will allow the Fenwick Labs to acquire new equipment, refresh older equipment, and expand the capabilities of the labs. c) Need for Project Including Risk Avoidance The Fenwick Labs expansion will: Enhance the evaluation capabilities of the Substation Automation Lab and the Power Systems lab; Integrate capabilities of the Controls Lab and the Distribution Grid Analytics Lab spaces; and Create a Technology Transfer Center that will provide a hands-on environment for engineers, field employees, and operators that supports conveying learnings from the latest technology assessments, conducted by SCE and other entities (as appropriate). The Substation Automation Lab is currently equipped to support automation testing for distribution-level substations, which typically monitor and control an average of 30 intelligent electronic devices. To support automation testing for larger substations, which can monitor and control an average of over 200 intelligent electronic devices, SCE must increase its lab capabilities. To support and safely integrate increasing renewables and DERs on the transmission and distribution system, SCE needs an expanded representation of its system. The Power Systems Lab utilizes a real time digital simulator (RTDS) to simulate and test advanced protection control applications for SCE s transmission and distribution system in real time. The RTDS can support many applications, including relay protection, control system testing, advanced wide area protection system, synchrophasor applications, special protection schemes, distribution system application, and renewables and distributed generation integration analysis. Having RTDS in-house also allows SCE to 18

20 conduct comprehensive testing before making widespread field deployments. This is a prudent approach that avoids potentially costly errors or setbacks in operations. SCE is expanding the Power Systems lab to accommodate upgrades to the RTDS racks and put in additional peripheral equipment. This will enhance configurations and capabilities and allow SCE to examine: How system restoration procedures should be improved with high penetration of renewables; How DERs will affect the transmission operations; and How we can foster grid stability and damp oscillations within a high renewable area. Undamped power system oscillations can lead to grid instability. 19 As DERs and energy storage become prevalent, these resources must be integrated into the safe and reliable operations of the grid. The Controls Lab and Distribution Grid Analytics Lab model simulate and analyze grid operations with high penetrations of DERs at the distribution level. At the Controls Lab, we focus on testing the physical DER controls in real time. The Grid Analytics Lab simulates power flows using Advanced Meter Infrastructure (AMI) data and circuit models. To help SCE advance to a more modern grid, the equipment and software we use to test and evaluate must be kept current. New and updated equipment and software improve the accuracy of analysis, help ensure lab capabilities map to more recent technologies, test and validate vendor claims of newer system capabilities, promote safety and reliability, and help us determine if and how widespread deployments can occur on SCE s grid. The Controls Lab will increase our abilities to assess and simulate the ramifications of increasing penetration of DERs on the grid over the next five years. As DER penetration increases, engineers and grid operators can no longer make power flow assumptions based on one-way power flow. This requires new simulation capabilities to process and analyze DER-related systems data. 20 Examples of DER-related systems data include load data (e.g., AMI, SCADA), 19 Local oscillation has been observed for renewables due to incorrect settings by the generator owner. 20 To address these immediate operational needs, SCE is requesting a Grid Analytics Applications software tool (SCE-04, Vol. 2, Information Technology). Our request aligns with (and is not duplicative of) the System Modeling Tool (SMT) (SCE-02, Vol. 10, Grid Modernization). 19

21 20 Workpaper Southern California Edison / 2018 GRC economic data (e.g., cost of solar PV, storage), and results data (e.g., voltage, current, real and reactive power). DERs can alter the direction of power flow. Due to their dynamic nature, the power flow can significantly vary within short time intervals. Therefore, accurate and detailed situational intelligence is needed to provide full insight into DER behavior. Situational intelligence at the distribution level will let us understand the behavior of the circuits and the power flow down to line segment levels. Such capability is needed so we can adequately support the Commission in the DRP and IDER proceedings. We require extensive circuit modeling to manage increasing DER resources. SCE s further integration of its modeling environment in the Distributed Grid Analytics Lab will gradually increase the number of circuits, until the full SCE system can be modeled down to the service transformer and customer meter levels. These modeling systems will be a hybrid of software and hardware. Specific equipment includes Power flow solvers, which support a fuller understanding of real and reactive power. Flow down to line segments and service transformers help fully capture the dynamic behavior of the distribution circuits, especially under high penetration DERs. This type of complex and granular modeling requires parallel processing servers to solve the problems within acceptable time frames. Interface servers and protocol conversion interfaces enable the power flow solvers to communicate with disparate DER systems. Finally, once the DERs are simulated and interface with the power flow solvers, large volumes of data are generated. This data needs to be analyzed via the analytics software, and presented in a manner which allows engineers and system operators to properly assess how the circuits behave with and without the high penetration of DERs. The Fenwick Labs also must upgrade and replace equipment for the lab network. The lab network supports all the labs within Fenwick, and provides a stand-alone test environment, allowing for integrated testing. All the labs are interconnected to allow us to evaluate technology across a broad spectrum of SCE grid needs. The lab network also maintains functional copies of production hardware and software. This allows us to completely simulate, test, and prove out emerging technologies prior to placing any of these technologies in in service on the grid. These upgrades and replacements will help ensure the network remains stable, while also allowing for necessary expansions of the network to support the growing volume of data and technology integration needs of the labs. SCE conducted an extensive survey comprising leading research universities, private companies, and research consortiums to determine whether any entity possesses the capabilities to address SCE s immediate operational concerns, such as providing extensive circuit modeling to 20

22 increase DER resources. Specifically, SCE requires extensive circuit modeling of SCE s entire distribution system. SCE requires long-term dynamic testing of emerging technologies in a simulated, integrated grid environment to test for reliability and safety. The simulated grid environment offered by the labs accurately reflect current real-life grid conditions as the grid continues to age and change. Our survey identified no single entity that can address all of SCE s operational concerns or has the diverse capabilities of Fenwick Labs. 21 Therefore it is more efficient to leverage the existing labs and experienced staff, rather than attempting to piece-meal all the work to multiple third parties for these same testing and evaluation services. d) Scope and Cost Forecast 22 As shown in the Table below, SCE forecasts the total cost of these enhancements to equipment and software will be $ million from These estimates were developed using existing contracts, recent purchases or accounting/engineering estimates. Please see below for further details: Year Cost Description of Expenditures 2016 $4.274M Refresh/upgrade real-time digital simulators for the Power Systems Lab Refresh a high-power AC/DC power source and acquire a new AC/DC power source for the Garage of the Future Purchase a controls system test bed to support hardware in the loop testing for the Controls Lab Purchase a data warehouse and 3TB of storage for the Distribution Grid Analytics Lab Purchase a new digital load/generation simulation system for the Distribution Grid Analytics Lab Purchase two power quality data acquisition systems for the Distribution Grid Analytics Lab Improve facility test infrastructure - minor improvements to retool lab to accommodate different types of testing operations Purchase relays to expand testing in the Controls, Power Systems, and Substation Automation Labs 21 For additional survey details, please refer to WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers AT Technical Testing Facility Survey w Blinded Results). 22 SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers). 23 The costs for the structural improvements needed at the Fenwick Lab are included in SCE-07, Vol. 3. The costs shown here represent the new and replacement equipment for the project. 21

23 22 Workpaper Southern California Edison / 2018 GRC 2017 $4.693M Refresh/upgrade real-time digital simulators for the Power Systems Lab Purchase hardware and software technologies for use in big data test applications for the Distribution Grid Analytics Lab Purchase an additional 2TB of data storage for the Distribution Grid Analytics Lab Improve facility test infrastructure - minor improvements to retool lab to accommodate different types of testing operations Purchase two power system simulators for the Substation Automation Lab Purchase additional visualization hardware and installation for new and expanded lab facilities Purchase relays to expand testing in the Controls, Power Systems, and Substation Automation Labs Refresh computers and monitors for Substation Automation, Grid Edge Solutions, and Distribution Automation Labs 2018 $4.195M Refresh/upgrade real-time digital simulators for the Power Systems Lab Purchase an additional 7TB of data storage for the Distribution Grid Analytics Lab Purchase an additional controls system test bed to support hardware in the loop testing for the Controls Lab Purchase two power quality data acquisition systems for the Distribution Grid Analytics Lab Purchase relays to expand testing in the Controls, Power Systems, and Substation Automation Labs Improve facility test infrastructure - minor improvements to retool lab to accommodate different types of testing operations 2019 $6.258M Refresh/upgrade real-time digital simulators for the Power Systems Lab Refresh scalable video display and associated specialized construction Purchase 5.5TB of data storage to support the increase in data required for simulating larger portions of the electrical grid - Refresh four power system simulators and purchase three new power system simulators Purchase two new digital load/generation simulation systems to increase the simulation and analytic abilities of the Controls Lab Purchase a controls system test bed to expand the electrical system simulations for the Controls Lab Purchase relays to expand testing in the Controls, Power Systems, and Substation Automation Labs Purchase a power quality data acquisition system for the Distribution Grid Analytics Lab Improve facility test infrastructure - minor improvements to retool lab to accommodate different types of testing operations 22

24 $9.556M Refresh Advanced Technology Lab Network hardware to provide increased connectivity between labs Refresh/upgrade real-time digital simulators for the Power Systems Lab Refresh Technology Transfer Center Equipment, including: benches for simulations; test relays; and a digital simulator Purchase an additional 7TB of data storage for the Distribution Grid Analytics Lab Purchase a controls system test bed to expand the electrical system simulation for the Controls Labs Refresh digital content in the labs to inform visitors of the work being conducted in the labs Purchase relays to expand testing in the Controls, Power Systems, and Substation Automation Labs Refresh computers and monitors for the Garage of the Future, Distributed Energy Resources, Power Systems, and Situational Awareness Labs Purchase a power quality data acquisition system for the Distribution Grid Analytics Lab Improve facility test infrastructure - minor improvements to retool lab to accommodate different types of testing operations Pomona Laboratory Expansion a) Capital Forecast Table V-5 Pomona Laboratory Expansion Forecast (Nominal $000) Capital Expenditures (Nominal $000) Project No CET-OT-OT-AT $1,635 $1,701 $1,205 $1,320 $1,390 $7, b) Project Description Since 1993, SCE has operated the Pomona Laboratory (Pomona Lab) to test, evaluate, and validate the performance reliability and safety of emerging electric and hybrid vehicles and their energy storage battery technologies. The Pomona Lab is approved by the U.S. Department of Energy to evaluate electric vehicle baseline performance and fleet operations. SCE couples electric and hybrid vehicles with stationary electric storage technologies, due to the commonality of applications. 23

25 24 Workpaper Southern California Edison / 2018 GRC The Commission approved funding for the energy storage and transportation technology test facilities and pilot programs in SCE s 2015 GRC decision. 24 The current capital request includes funds to: Test 12 Modified Test Vehicles, 8 class-5 25 Plug-in Hybrid Electric Vehicle (PHEV) trucks and 4 PHEV pickup trucks; Install new testing infrastructure, new and replacement equipment; and Expand and update existing lab facilities to increase testing capabilities for energy storage and electric transportation. c) Need for Project Including Risk Avoidance The Pomona Lab tests and evaluates alternative fuel and electric vehicles, and fleet vocational equipment (e.g., stationary generators, lifts and power tools). Past testing has provided vital information that has helped inform SCE s projects and activities. Based on recent advanced testing, SCE added Mitsubishi Outlander Plug-in Hybrid Electric Vehicles (PHEV) Sport Utility Vehicles (SUVs) to its vehicle fleet. Another example is found in the Pomona Lab s work in evaluating PEV charging infrastructure power quality. This work supported California s Title 20 battery charging efficiency standards with the test procedures to determine efficiency. 26 This work influenced the Society of Automotive Engineers (SAE s) 27 standards for Power Quality Requirements for Plug-in Electric Vehicle Chargers 28 and Power Quality Test Procedures for Plug-in Electric Vehicles. 29 The work also informed SCE s selection and approval of Electric Vehicle Supple Equipment (EVSE s) for SCE s Workplace Charging Pilot. Testing and evaluating the Modified Test Vehicle, alternative fuel PHEV Class 5 trucks and PHEV pickup trucks will encompass examining the vehicles range, energy consumption, capabilities, charging system impact, and reliability under various utility duty cycles. All of this work helps us choose wisely and operate the vehicles safely and efficiently. 24 D , pp Heavy-duty vehicle with a gross vehicle weight rating between 16,001 and 19,500 pounds as defined by the Environmental Protection Agency. In SCE s fleet, these vehicles are utilized as trucks with material handling booms/cranes and line trucks. 26 Codes and Standards Enhancement Initiative for PY2011: Title 20 Standards Development; Proposed Title 20 California Efficiency Standards for Battery Charger Systems. 27 SAE defines standards for the domestic automotive market. 28 See 29 See 24

26 The Pomona Lab s current space constraints limit its capacity to support testing of electric transportation technology. SCE evaluates electric vehicle charging infrastructure to make sure that the large numbers of electric vehicles connecting to the grid, including SCE s fleet, do not adversely affect the safety and reliability of operations or customer service. However, the lack of space limits SCE s ability to test and evaluate fast-charger technology. 30 Today, many available vehicles are capable of fast charging; the popularity of this emerging technology with automakers is growing, with several automakers planning on developing more vehicles with even higher power levels. As configured, the Pomona Lab is not equipped to evaluate fast-charging technology or electric vehicles with fast-charging technology. The Pomona Lab expansion will repurpose previously unused yard space into outdoor testing space. The expansion of the Electric Vehicle Supply Equipment (EVSE) test infrastructure will allow SCE to evaluate the grid impact from fast-charging capable vehicles and will enable SCE to evaluate Vehicle to Grid two-way exchanges of energy. In addition, the request includes funding for charging infrastructure test equipment, data acquisition equipment, and emission and fuel measurement instruments. The Pomona Lab has yielded significant operational knowledge concerning energy storage systems. SCE tests and evaluates various energy storage technologies from the basic components (e.g., battery cells, battery modules, communication, and monitoring and control equipment), through complete small-scale system testing in a laboratory environment. This capability differs from the other labs and pilot projects, which test and/or pilot full-scale battery energy storage systems. SCE s testing and evaluation of energy storage systems has provided safety and reliability information that helps us better integrate energy storage systems onto SCE s grid. For example, SCE tested each of the components, which comprised the Tehachapi energy storage system 31 at its Pomona Labs. SCE engineers conducted eleven rounds of component testing prior to allowing the manufacturer to commission the full system. Each round of component 30 Charging at a higher rate than AC Level 2, as defined in the Standard Automotive Engineers (SAE), Standard J SCE s Tehachapi Wind Energy Storage Project (TSP) was funded in part by the Department of Energy as part of the American Recovery and Reinvestment Act funding and in part by SCE s customers per Commission Resolution E TSP was not funded as part of a general rate case proceeding and is used as an example of the type of work performed in our Pomona Labs. 25

27 26 Workpaper Southern California Edison / 2018 GRC testing discovered problems with the system s safety and operational algorithms, and resulted in a software update. Absent this evaluation, the main system would have taken several months to commission, diagnose, and repair in a remote field environment. This would have increased costs and delayed the successful delivery of the project. Final system acceptance testing would have taken many months. Instead, it only took us two weeks to perform this work because we were able to address issues beforehand in laboratory conditions. Similarly, lab testing for the residential energy storage units helped us efficiently and successfully deploy and operate the Irvine Smart Grid Demonstration residential energy storage units. The lab testing identified various over 400 safety and design issues in the early models. Without this testing, we would have seen serious safety and reliability issues, including potential fire issues. While some errors still occurred in the field, safety measures developed in lab testing and evaluation helped us avoid any safety issues. Besides the residential energy storage units, SCE thoroughly tested the Irvine Smart Grid Demonstration Community Energy Storage device and Solar Car Shade Battery Energy Storage System (BESS) in the lab, before commissioning and operating these systems in the field. Again, lab testing allowed SCE engineers to gain operational experience with the systems, and address safety and reliability issues with the manufacturers in a safe, controlled environment with no grid impact prior to operating the deployed systems on SCE s grid as part of the Irvine Smart Grid Demonstration (ISGD) project. 32 Without the lab testing beforehand, these safety and reliability issues would have likely surfaced in the field and would have led to additional delays and costs. Pomona Lab s capacity to support the energy storage demonstrations required by the DRP proceeding, and the Commission s energy storage mandate, is constrained by lab space. SCE cannot test medium-sized energy storage systems (designed for small commercial, or industrial customers) or common storage elements for large utility energy storage systems. In light of the number of different battery systems emerging, and the needs associated with SCE s DRP demonstrations, our proposed expansion of the Pomona Lab and installation of new testing infrastructure and equipment at 32 The Irvine Smart Grid Demonstration (ISGD) was funded in part by the Department of Energy as part of the American Recovery and Reinvestment Act funding and in part by SCE s customers per D ISGD was not funded as part of a general rate case proceeding. 26

28 the Advanced Energy Storage Test pad 33 will allow SCE to test and evaluate a greater variety of battery energy storage systems. The lab expansion will allow SCE to run more simultaneous simulations. This reduces the overall test time, allows a greater number of tests, and can expedite the timelines for demonstration projects. It is vital that SCE test and evaluate the above-mentioned emerging technologies, so we can make sure that any integration on the grid is safe and reliable for our customers. To support these activities, SCE must expand existing laboratory facilities, install new test infrastructure and equipment (Advanced Energy Storage Test Pad), upgrade existing lab test equipment, and replace deteriorated equipment, including aging battery cyclers, environmental chambers and data acquisition systems. As with the Fenwick Labs, SCE conducted an extensive survey comprising leading research universities, private companies and research consortium to determine whether any entity possesses the capabilities SCE needs. Specifically, SCE needs long-term, dynamic testing, which simulates an integrated grid environment for energy storage systems, electric vehicles and vehicle charging equipment. Survey results show no single entity possesses all of SCE s needed capabilities. 34 Given that SCE can leverage the existing Pomona Lab structure, and skilled and experienced staff are already in place, expanding the Pomona Lab to increase testing capabilities on electric transportation and larger scale energy storage systems represents the most efficient way to address SCE s testing and evaluation needs. The ability to conduct EVTC testing allows SCE to efficiently and accurately assess new technologies and their impacts on grid reliability and safety. Testing in the simulated grid environment of the Pomona Lab improves our ability to support California s transportation electrification, energy storage and other energy and environmental policy goals. 33 The Advanced Energy Storage Test Pad is a large, outdoor concrete area designed to accommodate various large, outdoor-rated, commercial, industrial, and utility-sized energy storage systems. The pad will be designed to integrate with the Pomona Lab test infrastructure, as well as additional test connections and data acquisition systems. 34 For additional survey details, please refer to WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers AT Technical Testing Facility Survey w Blinded Results). 27

29 28 Workpaper Southern California Edison / 2018 GRC d) Scope and Cost Forecast 35 As shown in the Table below, SCE forecasts the total cost of these enhancements to equipment and software will be $7.25 million from Cost forecasts are based on current and historical quotes. 36 The lab refresh equipment cycles are based on manufacturer data (when available), historical breakdown data for the equipment, and Pomona Lab engineering. This means that not all lab equipment is refreshed every year. For example, there are 18 humidity-controlled environmental chambers in the Pomona Lab, which have an estimated life of 6-10 years. Since these machines were not all purchased in the same year, the refresh cycles are staggered across multiple years. We also consider equipment breakdown records when selecting equipment for refresh. We may refresh equipment outside of its predefined refresh cycle due to the documented frequency of breakdowns. As such, the table below shows instances of equipment refresh in multiple years. Please see below for additional details: Year Cost Description of Expenditures 2016 $1.635M Refresh of standard-sized temperature and humidity controlled environmental chambers for use with battery and energy storage system (ESS) testing. Refresh of medium and high power advanced bidirectional cycler 37 for use with battery and ESS testing for medium power, for high power. Refresh of low and high power grid simulator for use with ESS and electric vehicle supply equipment (EVSE) testing for low power, for high power. Purchase of new vehicle data acquisition system to expand testing capabilities for vehicle testing. Refresh of fuel flow meters for use with vehicle testing, Purchase of a lab network data control, collection, and analyzer to expand testing capabilities in the lab for use with ESS testing. Facility test infrastructure -- minor improvements to retool lab to accommodate different types of testing operations for ongoing ESS, EVSE, and vehicle testing $1.701M Refresh of standard-sized temperature and humidity controlled environmental chambers for use with battery and energy storage system 35 SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers). 36 Ibid. 37 Highly sophisticated, precise, programmable battery equipment that allows a battery to cycle (i.e., to perform a charge (energy into the battery) and discharge (energy out of the battery)). 28

30 29 (ESS) testing. Refresh of medium power advanced bidirectional cycler for use with battery and ESS testing. Refresh of dynamic power smart load banks for use with ESS and EVSE testing. Refresh of low power grid simulator for use with ESS and electric vehicle supply equipment (EVSE) testing. Refresh of data acquisition systems for use with ESS and EVSE testing. Purchasing an emissions testing unit for use with vehicle testing. Facility test infrastructure -- minor improvements to retool lab to accommodate different types of testing operations for ongoing ESS, EVSE, and vehicle testing $1.205M Refresh of medium power advanced bidirectional cycler for use with battery and ESS testing. Refresh of static power load banks for use with ESS and EVSE testing. Refresh of high power grid simulator for use with ESS and electric vehicle supply equipment (EVSE) testing. Refresh of fuel flow meters for use with vehicle testing total. Facility test infrastructure -- minor improvements to retool lab to accommodate different types of testing operations for ongoing ESS, EVSE, and vehicle testing $1.320M Refresh of walk-in temperature and humidity controlled environment chamber for use with battery and ESS testing. Refresh of data acquisition systems for use with ESS and EVSE testing. Purchase of an emissions testing unit for use with vehicle testing. Facility test infrastructure minor improvements -- retool lab to accommodate different types of testing operations for ongoing ESS, EVSE, and vehicle testing $1.390M Refresh of standard-sized temperature and humidity controlled environmental chambers for use with battery and energy storage system (ESS) testing. Refresh of medium power advanced bidirectional cycler for use with battery and ESS testing. Refresh of dynamic power smart load banks for use with ESS and EVSE testing. Refresh of data acquisition systems for use with ESS and EVSE testing. Refresh of fuel flow meters for use with vehicle testing. Facility test infrastructure -- minor improvements to retool lab to accommodate different types of testing operations for ongoing ESS, EVSE, and vehicle testing. 29

31 30 Workpaper Southern California Edison / 2018 GRC Equipment Demonstration Evaluation Facility a) Capital Forecast Table V-6 Equipment Demonstration Evaluation Facility (EDEF) Forecast (Nominal $000) Capital Expenditures (Nominal $000) Project No CET-OT-OT-AT $3,666 $2,283 $528 $544 $562 $7, b) Project Description The EDEF is a high-voltage test facility located within an existing SCE substation, which was built to test a variety of new technologies to support renewables integration, grid modernization, infrastructure replacement, and safety enhancements. The EDEF allows SCE engineers to evaluate largely unproven emerging technologies on energized high-voltage equipment and distribution circuits. These evaluations occur under real-world conditions and are crucial to determining operational successes and failures before we deploy the technologies. Testing capabilities include: Fault Testing (High Impedance or Other): High impedance fault detection testing on circuits feeding customers was not previously possible, due to the serious safety hazards a downed line would create. In addition, performing lab simulations of high impedance faults is difficult, as very little data on the characteristics of these types of faults exists. Since EDEF was designed to include areas of sand, poles, subterranean vaults, asphalt, and cement, engineers can now test for different types of high impedance faults and develop appropriate mitigation strategies to protect our customers and the public. Construction/Installation Methods Validation: Presently, apparatus engineers must develop installation standards prior to piloting any devices. However, engineers may not be certain of the methods for proper deployment and operation, given their limited experience with such equipment. EDEF provides engineers with the opportunity to become familiar with the equipment, while investigating the safest and most effective way of installing the various devices. 30

32 Distribution and Substation Automation: As technologies continue to evolve and additional demands are placed upon the system, SCE will need to deploy a variety of communicating field devices on its distribution circuits and substations to enable distribution and substation automation. These devices include controls for capacitor banks to help achieve advanced volt and VAR control goals on the distribution system, relays and switching equipment to help SCE isolate faults and reconfigure circuits to restore power to customers more quickly, and the high-speed communication network needed to tie everything together. With EDEF, SCE engineers will be able to safely demonstrate these communicating field devices and necessary communication networks prior to piloting. In this way, engineers will be able to test and judge the viability of these devices in a harsh, high-voltage environment. We simply cannot duplicate this environment in the laboratory. The flexibility provided by successful and accurate testing of these devices will allow SCE to better integrate and optimize customer-interconnected distributed energy resources (DER). By developing and constructing an EDEF, SCE will improve engineering and power delivery processes by obtaining crucial information on equipment capabilities and operations. There is increasing pressure to replace and upgrade infrastructure, and it is increasingly important to validate equipment performance in an energized facility prior to piloting or deploying that equipment on the power grid. This 12kV Test Track facility will provide SCE the ability to pre-test new equipment and/or systems without adversely affecting or disturbing customers. It also allows T&D to conduct tests in a safer environment than evaluating on live customer circuits in the field. SCE requested funding for the EDEF in the 2015 General Rate Case to develop the ability to test and evaluate emerging technologies in a live grid environment. 38 No party opposed the request 39 and SCE proceeded with construction. SCE planned the EDEF project in 2013 and prepared the location for site improvement in In 2015, SCE began constructing the facility. In November 2015, the Commission issued its 2015 GRC Decision. The Commission disallowed the EDEF project because SCE has not shown that the technical problems it 38 A , Exhibit SCE-03, Vol. 2, at pp D , p

33 32 Workpaper Southern California Edison / 2018 GRC would address are unique to SCE and that other more cost-effective options do not exist for doing this research. 40 However, as of December 2015, SCE had already spent $5.2 million on the project. SCE was constructing and finalizing the site. At that point, SCE concluded that it would be more prudent to finish the project, rather than forgo the sunk costs. c) Need for Project, Including Risk Avoided While the Fenwick and Pomona labs enable engineers to perform technology evaluations under simulated conditions, the EDEF allows us to evaluate energized equipment in a live circuit, high-voltage environment. There can be significant differences with respect to modeling and lab testing and how a technology reacts in the live circuit environment. Moreover, there are some items that simply cannot be effectively tested in a lab, or safely and reliably tested on a live customer circuit. For example, SCE recently conducted high impedance fault tests, to better detect when a wire is on the ground and obtain prompt notification of the situation. 41 As discussed in SCE-02, Volumes 1 and 8, energized downed wires are a significant public safety risk. Our current mitigation programs focus on upgrading small wire and adding branch line fuses. Both of these efforts are designed to reduce the probability of wire down events. At EDEF, our efforts focus on developing alternate mitigations that can actually detect energized wire down events and respond quickly to de-energize the compromised conductor. These initial tests conducted at EDEF demonstrated new technologies, which show real potential to address this public safety concern. Technology evaluations using EDEF live circuits are also necessary to evaluate equipment, to better determine grid readiness prior to deployment; this is the logical next step in the work conducted in the Advanced Technology Labs and augments SCE s existing technology evaluation capabilities. The key to successful smart grid deployments is testing, evaluating and validating a technology s potential for real-world application. Prototype devices allow engineers to test and evaluate performance at a smaller scale, which helps identify any potential scale-up issues before a device is piloted on customer circuits. Since the circuit at EDEF does not service customers, it will allow SCE to 40 Id. at p For additional details, please refer to WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers, EDEF: Spread Spectrum Time Domain Reflectometry for Fault Detecting in an Electricity Distribution System Phase 2A Extension, Final Report). 32

34 conduct energized demonstrations and evaluations of how emerging technologies may (or may not) be placed onto our system. Substation and distribution automation requires deploying a variety of communicating field devices on its distribution circuits. These devices include controls for capacitor banks and switching equipment to help SCE locate faults and reconfigure circuits to restore power to customers more quickly. Advanced substation and distribution automation is a key component to Grid Modernization to support high integration of DERs. EDEF provides SCE a live, energized environment to safely evaluate communicating devices and communication networks. Advancing these communicating devices and communication networks for substation automation will allow SCE to further integrate DERs onto its distribution grid. With respect to the Commission s determination that SCE had not shown that EDEF would address issues that are unique to the company, EDEF was not designed for that purpose. SCE identified a specific need for a set of capabilities that would allow it to safely, reliably, and prudently accelerate testing and deploying new technologies to support California s energy and environmental goals, and specifically with respect to its fault detection activities, work to improve grid safety. The standard in judging these expenditures is whether they are prudent. California s energy and environmental policies are leading the nation and driving the change. The Commission s focus on improving customer, employee, and public safety is supported by EDEF. In response to the Commission s query whether more cost effective options exist to do this work, SCE conducted an exhaustive survey of research laboratories, research universities, and research consortiums to determine whether any entity meets SCE s specific testing and evaluation needs. Specifically, SCE needs a facility that can provide evaluation of emerging technologies on a live circuit that replicates SCE s distribution grid environment. With these capabilities, we can address concerns that are specific to its system. The results of the surveys show that EDEF is the most efficient means to execute this work. While other entities possess testing and evaluation capabilities, no entity can provide all of the capabilities at EDEF, nor can they provide the flexibility of testing options available at SCE s facility. No entity other than EDEF possesses the vital testing and evaluation 33

35 34 Workpaper Southern California Edison / 2018 GRC capability to simulate voltage frequency and real and reactive power (utility and customer loads) on a live distribution circuit. A copy of the survey results is included with our workpapers. 42 In designing and constructing EDEF, SCE minimized land and construction costs of the facility by using available land at its existing Shawnee substation. The test circuit is a short distance from the main circuit breaker at the substation. This reduces equipment costs. The Shawnee site had enough room on its existing equipment to dedicate access to 12 kv for the test circuit, without compromising customer reliability or safety. (1) Scope and Cost Forecast 43 In 2015, SCE spent $5.2 million to design, construct, and purchase EDEF infrastructure, including load banks, capacitors and control room equipment. This $5.2 million also includes the construction of the 12kV test circuit at the site. In 2016, SCE will complete the final phase of construction for $3.67 million. These costs comprise $2.36 million for constructing the Control Room, additional Site Improvements to secure the facility, and $524,000 to procure and install equipment. SCE will also integrate the installation of Large Energy Storage Testing Apparatus (LESTA). This allows SCE to safely evaluate the performance of energy storage systems greater than 250 kw up to 6 MW and validates manufacturers performance claims prior to deployment on the grid. 44 The cost of this integration is $787,000. In 2017, SCE will complete constructing the control building and procuring and installing new equipment and devices for a total cost of $2.28 million. In years 2018 through 2020 (at a cost of $528,000, $544,000 and $562,000 respectively), SCE will procure, replace, and install lab tools and equipment. B. Energy Storage Pilots Energy storage can potentially help transform our grid, and enable more widespread use of renewable resources. To integrate storage, SCE plans to conduct pilots to better understand energy storage performance and cost competitiveness, and making sure electric service remains safe and reliable as more energy storage is integrated onto the grid. Figure V-5 below shows the capital forecast 42 For additional survey details, refer to WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers AT Technical Testing Facility Survey w Blinded Results). 43 SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Advanced Technology Laboratories Workpapers). 44 See A , Exhibit SCE-03, Vol. 2, Engineering and Grid Technology, p

36 for our Distributed Energy Storage Integration (DESI) program, including the program s proposed expansion. Figure V-5 Energy Storage Pilots Recorded /Forecast Portion of WBS Element CET-OT-OT-AT (CPUC-Jurisdictional Constant 2015 and Nominal $000) Distributed Energy Storage Integration (DESI) Pilot Program a) Capital Forecast Table V-7 Distributed Energy Storage Integration (DESI) Pilot Program Forecast (Nominal $000) Capital Expenditures (Nominal $000) Project No CET-OT-OT-AT $8,448 $14,518 $22,499 $15,317 $7,801 $68, Refer to WP SCE-02 Vol. 11, p

37 36 Workpaper Southern California Edison / 2018 GRC b) Project Description The 2015 GRC Decision approved the Distributed Energy Storage Integration (DESI) Pilot Program. We developed the DESI Pilot Program to test the ability of a Battery Energy Storage System (BESS) to provide feeder load relief, give voltage support, and smooth the delivery of energy from renewable distributed generation to the grid. DESI will also establish the aggregation and control of multiple systems and the ability of energy storage systems to integrate to the grid safely and reliably. Specifically, the three DESI pilot systems are focused on how to best integrate energy storage onto the grid. The projects in DESI demonstrate a progression in complexity related to communications and control. DESI 1 is a single self-contained energy storage system with basic communication capabilities we developed in In 2017, DESI 2 will use advanced controls and monitoring, and integrate grid operations and distributed energy resources. In late 2017, DESI 3 will support the aggregation of multiple systems. Together, these projects will inform future deployments and in developing advanced network infrastructure. During 2015, SCE installed the first DESI pilot (DESI 1), a 2.4 MW, 3.9 MWh lithium-ion battery system. This pilot project was installed on private industrial property in the City of Orange. The BESS is connected directly to a 12kV distribution circuit and supports the circuit during periods of high demand by discharging energy from the BESS. The BESS operates autonomously by monitoring the dynamic conditions on the 12kV circuit. Typically, the battery charges during off-peak periods. DESI 1 has two operating modes: real power (in watts) and reactive power (in VARs). SCE will continue to monitor the performance of DESI 1 to refine its operating capabilities. SCE intends to test how DESI 1 can be a dual-use machine; besides providing grid reliability, the system will actually participate in the wholesale market. There will be learnings associated with managing the system between the two uses, with the priority being grid reliability, and in verifying the availability of the system for market participation. DESI 2, a 2 MW, 4 MWh lithium-ion battery system will test grid operations for reliability purposes. DESI 2 will incorporate advanced controls and lessons learned from DESI 1. The system will be controlled and monitored, utilizing SCE s upcoming Integrated Grid Project (IGP) The IGP is funded through our Electric Program Investment Charge. 36

38 demonstration control system. This will provide a unified control and communication platform for grid operations and distributed energy resources, including energy storage. DESI 2 will be associated with circuits to support SCE s Preferred Resource Pilot (PRP) programs. DESI 3 will pilot the optimization of distributed storage (aggregation of multiple systems) in the PRP deployment area and is planned for installation in The project scope includes three systems, each rated at 250 kw / 250 kwh. The project will develop the controls and integration of utility controlled energy storage systems (utility or third party owned) and help identify additional distribution circuit benefits. Those benefits include potentially extending equipment life and enhancing DER integration; and phase balancing and voltage optimization. To continue to support market transformation, and help safely and reliably integrate energy storage on the grid, SCE will expand the pilot program from the initial three pilots previously approved to an additional ten pilots. Whereas the previous pilots focused on how to integrate energy storage onto the grid, the ten new pilots will focus on extracting value from energy storage projects and sharing the lessons learned. 47 c) Need for Project Including Risk Avoided The Commission s Energy Storage Procurement Framework and Design Program Decision 48 set a goal to transform the energy storage market to overcome the barriers that are hindering broader adoption of emerging technologies. 49 This energy storage Procurement Framework and Design Program Decision established three guiding principles for the Commission s energy storage procurement policy: 1) Optimize the grid, including peak reduction, contribution to reliability needs, or deferment of transmission and distribution upgrade investments; 2) Integrate renewable energy; and 3) Reduce greenhouse gas emissions by year 2050 to 80 percent below 1990 levels The deployment location of the pilots will depend on the identified need of the system, timing, and other criteria. 48 D Id. p Id. at pp

39 38 Workpaper Southern California Edison / 2018 GRC The Commission s decision also established an energy storage mandate for SCE of 580 MW. The systems must be procured by 2020 and operational by The pilots we propose will provide needed data and lessons learned to support the Commission s energy storage policy goals, while helping ensure that integrating energy storage does not diminish safety and reliability for our customers or workers. Lessons learned can help inform Commission efforts such as the DRP and the Integrated Distributed Energy Resources proceeding. There are few industry energy storage projects that address distribution reliability. Recognizing the need to help ensure best practices in safety and operating procedures for energy storage, the Commission is convening an Energy Storage Safety Working Group. The group is composed of the California investor-owned utilities, energy storage manufacturers (i.e., NGK Insulators and NEC Energy Solutions), and the Office of Ratepayer Advocates. The Working Group s aim is to help the Commission develop a short list of inspection guidelines for ES systems co-located at utility substations or at generation facilities. 51 (1) Diversity of Applications SCE intends the DESI Pilot Program expansion to support various capabilities, including but not limited to: enhancing distribution reliability, enhancing transmission substation reliability, integrating DERs, demonstrating dual-use (serving both a grid reliability function and participating in the market), fostering microgrids, and spurring electrification of transportation. The pilots supporting these applications may vary in technology type. Even though current deployments focus on lithium-ion batteries, other storage options and battery chemistries will be explored in the future. Systems will also vary in sizing based on the power and duration needs of the application, and whether or not the BESS will participate in the wholesale market. SCE will assess the benefits of energy storage, and we expect that the benefits will depend on the application. Identification and quantification of benefits for BESS must be tracked and validated, and will contribute to future benefit-cost discussions related to the viability of energy storage as a cost-effective tool as system costs decline. Benefits such as the deferral value of traditional capital upgrades and market participation may be quantifiable, but need to be validated and monetized. The DESI Pilot Program Expansion also aims to help us (on behalf of our customers) 51 Subject to Commission General Order

40 understand whether energy storage can provide benefits such as equipment life extension, voltage optimization, distributed energy resources integration enhancement, phase balancing, and reactive power compensation. Further learnings include power quality, or participating in N-1 contingency 52 scenarios. (a) Distribution Reliability SCE will pilot energy storage systems to test the feasibility of optimizing the grid through contribution to distribution reliability and to evaluate whether energy storage can contribute to grid needs. These pilot projects will use BESS as a tool to assess how energy storage can help mitigate distribution substation planning criteria violations, such as planned loading limit and duct-bank temperature violations. Potential pilot projects include: A pilot project planned for installation in 2017, connecting to a circuit in an urban environment, within the preferred resources pilot area. The project will be sited in an SCE right-of-way. We will pilot using energy storage to solve a forecast distribution need triggered by a planning criteria violation 53 of a duct bank temperature limit. 54 The energy storage project could potentially defer the installation of a new duct bank structure. A pilot project planned for installation in 2018 to assess whether energy storage can solve a forecast distribution need triggered by a violation of a planned loading limit, as defined in SCE s distribution substation planning criteria. A pilot project planned for installation in 2018, to assess how energy storage can potentially defer traditional capital upgrades related to an N-1 contingency to account for the outage or failure of a single transformer or major component at a distribution substation. (b) Facilitation of Preferred Resources SCE will pilot energy storage systems to integrate renewable energy and will target areas with existing high penetration of DERs. As the penetration of DERs (such as residential PV arrays) increases on the distribution grid, system upgrades will be required to mitigate 52 Outage or failure of a single transformer or major component at a distribution substation. 53 SCE has established Distribution Substation Plan criteria and guidelines, which identify approved design standards to serve forecast electric distribution customer load safely and reliably. These guidelines require staying within established equipment thermal limits during normal hours. 54 The duct bank houses the circuit cables in a substation. 39

41 40 Workpaper Southern California Edison / 2018 GRC the following potential impacts: (1) circuit overload; (2) voltage fluctuation; (3) reverse power flow; (4) system protection; and (5) system reconfiguration. SCE will test whether energy storage can mitigate some of these issues by: (1) charging when the generation on the circuit exceeds the load or the circuit capacity; and (2) discharging when the load is greater than the generation, or when circuit capacity is available. Energy storage can potentially minimize large generation output variation by smoothing the generation output -- discharging when generation decreases and charging when generation increases. This minimizes voltage fluctuation. In addition, the ability of a BESS to act as a generator or a load can improve a distribution circuit s capacity to support the power needs of customers. Potential pilot projects include: A pilot project planned for installation in 2018, connecting to a circuit in an urban environment with high PV penetration resulting from many residential PV installations. The system will determine whether energy storage can help minimize voltage fluctuation, and maintain voltage compliance. The system also enables greater conservation voltage reduction capabilities. A pilot project planned for installation in 2018, connecting to a circuit in a desirable PV area, such as the high desert, including mostly large PV installations. The system could increase the dependability of PV systems by supplementing their variable output. A pilot project planned for installation in 2019, connecting to a circuit with high PV penetration driven by a mix of small residential system and large installation. The system will be operated to maximize the benefits storage can provide and validate the stacking of various distribution values, such as supporting the circuit voltage, improving the dependability of PV, and minimizing reverse power flow. (2) Other Applications SCE will seek opportunities to pilot storage where the storage characteristics solve unique operational grid problems. The criteria for these types of projects would include: (1) leveraging the fast response of storage systems; (2) increasing grid resiliency for critical and/or remote loads; (3) supporting microgrid developments that provide resources that benefit a region on the grid; and (4) supporting projects that enable electrification and carbon reduction objectives. SCE will seek diversity of storage across climate zones and rural/urban mix and load patterns to evaluate 40

42 operating performance. Pilot projects in this category are still under evaluation, and the number (within the ten pilots aforementioned) and timing are to be determined as the technical requirements and system sizing are defined. (a) Fast Response The charge and discharge characteristics of energy storage and its voltage and reactive power (VAR) control capabilities are unique for distributed resources. The ability of the BESS to charge/discharge quickly may be a foundational component of a resource intensive distribution system. SCE is working with multiple parties (e.g., General Electric, Pacific Northwest National Lab, National Renewable Energy Laboratory, California Institute of Technology) on Network Optimized Distributed Energy Systems (NODES) to investigate real-time adaptive control systems that leverage storage in combination with other distributed resources. SCE plans to integrate these technologies to provide ancillary services at the distribution level. 55 (b) Grid Resiliency Similar to grid reliability, energy storage may also provide a resiliency benefit. To test for grid resiliency, SCE will seek to support customers with critical loads in remote areas where utility controlled storage may provide increased operating characteristics within a remote region. A potential 2018 project will address an N-2 contingency 56 scenario as an alternative to back-up diesel generators, supporting grid reliability and greenhouse gas reductions. A substation normally has three transmission circuits feeding its transformers, if two transmission circuits were lost due to a storm, an energy storage system could supply energy for customers for a limited time while crews repair the damaged equipment. (c) Microgrids Grid side storage may address challenges and opportunities associated with microgrid projects. Modern microgrids are primarily resourced with renewable sources, and therefore meet many of California s energy policy objectives. Enabling and integrating these complex systems onto the distribution grid will require specialized control systems and operating protocols between microgrid customers and SCE grid operators. Storage may play an important role in leveraging these microgrids to integrate and support the distribution grid and provide the individual 55 Proposed in A and approved by the Commission in D The potential loss of two transformers or major components at a distribution substation. 41

43 42 Workpaper Southern California Edison / 2018 GRC customer needs. Energy storage can provide resource optimization, resource integration for renewable energy, and load management. Two potential pilot projects include: A pilot project planned for installation in 2019, supporting a microgrid project connected to the front of the meter serving critical security loads. Examples of these loads could be, but are not limited to, law enforcement agencies, fire departments, etc. The microgrid will help ensure continued operation during an outage event through voluntary islanding. 57 Continued operations of key agencies, such as law enforcement agencies and fire departments will improve public safety during outage events. A pilot project planned for installation in 2020, supporting a microgrid project at a military base. This will help ensure continued operation of critical military loads during an outage event, and allow for voluntary islanding to serve national defense interests. (d) Electrification SCE may pilot the transition of a traditionally non-electric load to an electric load, (i.e. electrification). Energy storage may help offset the increased load that occurs when equipment and vehicles are electrified at a site. Energy storage may also help us defer capital upgrades. The potential pilot includes installation of an energy storage system to manage the load of cableconnected 58 trucks used to transport goods. The electrification of trucks supports the reduction of greenhouse gases and will be deployed in collaboration with the local air quality management district. d) Scope and Cost Forecast 59 SCE is projecting the total capital cost of $64.2 million from , as summarized in Table 1. To develop its forecast, SCE engaged in a competitive RFP process with multiple battery integration vendors responding to the RFP. Based on pricing and technical information provided in vendor RFP responses, SCE conducted a qualitative and quantitative analysis of vendor capabilities. SCE then selected a vendor that demonstrated recent experience in deploying battery energy 57 Islanding refers to the ability for the microgrid to operate independently of the distribution grid. 58 Also known as catenary. 59 SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Energy Storage Pilot Workpapers). 42

44 storage systems for our specified quantity and timeline, capable of operating under SCE parameters, while providing operational support and maintenance services, under best value contracted pricing. These estimates were developed using existing contracts, recent purchases or accounting/engineering estimates associated with acquiring the needed land (or interest in land), performing interconnection and distribution upgrades, and designing, constructing, commissioning, and testing the BESS. 60 The projects typically follow a two-year deployment timeframe. In year one, we acquire the land and complete design activities; we also initiate procurement and construction activities (including interconnection and distribution upgrades). In year two, we complete operational, procurement, construction, commissioning, and testing activities. In 2016, SCE intends to acquire land, complete project design, and initiate procurement and construction activities for three projects that will be operational in The cost is estimated at $8.4 million. In 2017, SCE plans to complete procurement, construction, commissioning, and testing for the three projects. We also plan in 2017 to acquire land, complete project design, and initiate procurement and construction activities for four year-2018 projects at a total cost of $14.5 million. In 2018, SCE will complete procurement, construction, commissioning, and testing for the four 2018 projects. We also plan to acquire land, complete project design, and initiate procurement and construction activities for three year-2019 projects at a total cost of $22.5 million. In 2019, SCE will complete procurement, construction, commissioning, and testing for the three 2019 projects. We also plan to acquire land, complete project design, and initiate procurement and construction activities for two year-2020 projects at a total cost of $15.3 million. In 2020, SCE will complete procurement, construction, commissioning, and testing for the two 2020 projects at a total cost of $7.8 million. C. Technology Integration After we have tested and evaluated emerging technologies at the Advanced Technologies Labs and in the field, and piloted technologies in an integrated grid environment, the technology can be deployed. Two such technologies are ready for further deployment on the grid: Distribution Volt VAR Control (DVVC) Program and the Advanced Outage Detection and Analytics Program. 60 Ibid. 43

45 44 Workpaper Southern California Edison / 2018 GRC Distribution Volt VAR Control and Capacitor Automation Program a) WBS Indicator of Project and Capital Forecast Table V-8 Distribution Volt VAR Control Capital Expenditures Forecast Portion of WBS Element CET-PD-LG-CV (Nominal $000) 3 Distribution Volt VAR Control Capital Expenditures (Nominal Project No. CET-PD-LG-CV $000) Forecast PCCs Replaced ,949 Total Cost $2,571 $2,651 $4,414 $4,558 $4,705 $18,899 Table V-9 Capacitor Automation Program Capital Expenditures Recorded /Forecast Portion of WBS Element CET-PD-LG-CV (Nominal $000) Project No. Capacitor Automation Program Capital Expenditures (Nominal $000) CET-PD-LG-CV PCCs Replaced Total Cost $1,605 $2,854 $0 $0 $0 $4,459 44

46 45 Figure V-6 Distribution Volt VAR Control Forecast Portion of WBS Element CET-PD-LG-CV-MTE 61 (CPUC-Jurisdictional Constant 2015 and Nominal $000) b) Project Description The Distribution Volt VAR Control (DVVC) Program centralizes control of the field and substation capacitors, to coordinate and optimize voltage and VARs across all circuits fed by a substation. Supervisory-controlled distribution substation capacitors and existing standard automated distribution field capacitors on distribution circuits are leveraged to reduce energy consumption, while maintaining overall customer service voltage requirements. 62 The DVVC is implemented at SCE as a centralized voltage and VAR control scheme through the Distribution Management System (DMS) and the Energy Management System (EMS) that controls the switching of existing capacitors in substations and on distribution circuits. The DVVC was authorized in the 2012 GRC, as part of the DMS. 63 The DVVC program has several objectives, including meeting both voltage and VAR requirements when possible, minimizing system 61 Refer to WP SCE-02 Vol. 11, p American National Standards Institute (ANSI) C84.1 standard and SCE s Rule 2 tariff. 63 Previously called Advanced Voltage VAR Control (AVCC). 45

47 46 Workpaper Southern California Edison / 2018 GRC voltage at the measured points within limits, minimizing energy consumption, minimizing capacitor switching, and operating within the local distribution field Programmable Capacitor Controls (PCC) settings. c) Need for Project Including Risk Avoided Distribution voltage and VARs are controlled using automated distribution substation capacitors and automated distribution field capacitors on distribution circuits. Control of these devices is automated, but each device acts autonomously based on conditions at its location. This current configuration helps ensure distribution voltages are boosted, but is less precise and causes higher than necessary energy consumption. Deploying DVVC as a grid integration solution will optimize voltage levels on the distribution system, reducing excess voltage, which results in avoided energy procurement and capacity costs, while not compromising the safety and reliability of service. SCE estimates these avoided energy procurement and capacity costs to provide a 1% actual savings in energy costs for customers per 1% reduction in voltage. 64 SCE s DVVC program was developed over many years through SCE s multiple pilot projects, field and laboratory testing at SCE s Advanced Technology Laboratories, and computer modeling and other industry analyses. 65 During the 1990s, the Distribution Capacitor Automation Project (DCAP) demonstrated energy savings greater than 2% on two distribution substations; however, broad implementation of the DCAP program required costly computer processing equipment and we concluded that a less costly software revision needed to be developed for system deployment. 66 The recent ISGD Project, provided a test bed for piloting the DVVC utilizing more modern control systems and programmable capacitor controls (PCC), which did not exist in the 1990 s, to validate potential voltage reductions and estimated energy savings associated with these technologies. SCE has demonstrated the voltage reduction, power factor correction, and energy savings of the centralized voltage and VAR optimization by DVVC Program See below for additional details. 65 See below. 66 For additional details, please refer to WP SCE-02 Vol. 11, pp (Capacitor Automation and DVVC Workpapers), and pp (Final TP&D Report Distribution Automation & DSEEP Support). 67 R. Yinger and M. Irwin, Technical Report Irvine Smart Grid Demonstration, a Regional Smart Grid Demonstration Project, Advanced Technology Organization, Southern California Edison Company, Rosemead, CA, December This document is awaiting final approval by the U.S. Department of Energy. 46

48 SCE s new DVVC program will replace the existing Capacitor Automation Program, providing a centralized control strategy. The ISGD project demonstrated that this centralized control strategy could result in a 2% voltage reduction, and a potential energy savings of 3.4%. 68 d) Scope and Cost Forecast 69 Figure V-7 Capacitor Automation Program Recorded /Forecast WBS Element CET-PD-LG-CV-MTW 70 (CPUC-Jurisdictional Constant 2015 and Nominal $000) SCE s Capacitor Automation program will continue to automate existing manual capacitor controls and upgrade obsolete, first-generation automation equipment until it is fully transitioned into the DVVC program. This transition will require additional engineering, design planning and field crew time for initial visits to implement the DVVC. In 2018, the DVVC program will serve as 68 E. Kamiab et al., Distribution Volt/VAR Control to Optimize Customer Voltage Profiles at Southern California Edison: Irvine Smart Grid Demonstration, EPRI, , Palo Alto, CA. 69 SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Capacitor Automation and DVVC Workpapers). 70 Refer to WP SCE-02 Vol. 11, p

49 48 Workpaper Southern California Edison / 2018 GRC the primary capital and O&M 71 funding mechanism for capacitor automation and PCC replacements. 72 Capacitor controls are used to remotely operate switched capacitor banks installed on the distribution system to provide voltage and reactive power (VAR) support. 73 Without capacitor banks, the voltage supplied to SCE customers would fluctuate to levels that can damage customers equipment or appliances, and present safety hazards. In addition, as DERs proliferate, large DER installations can increase voltage volatility on primary circuitry. To address these concerns, the circuit and substation voltage profiles must be continuously monitored and managed as a system rather than at independent locations through DVVC. This helps sustain VAR efficiency and maintain voltage limits across all circuits. During , we expect to see a rise in the volume of capacitor control replacements to support the implementation of DVVC throughout various areas of the SCE distribution system. There are approximately 13,750 capacitor banks in SCE s distribution system. Of these 13,750 banks, approximately 10,850 banks have radio-equipped PCCs installed. The plan for the DVVC program and the transitioning Capacitor Automation Program is to replace failed PCCs and PCCs nearing the end of their lifecycle. SCE expects to replace 695 PCCs in 2016, 886 PCCs in 2017, 695 PCCs in 2018, 697PCCs in 2019, and 698 PCCs in 2020 at an average cost of $6,380 ($2015) each. 74 In 2016, DVVC will be deployed within selected areas of SCE s service territory beyond pilot or research projects. The deployment of DVVC is planned to span three years ( ) at highly loaded distribution substations within the Los Angeles basin where a large potential for energy savings exists. This implementation is planned to occur at approximately 313 distribution substations. SCE is looking to deploy DVVC at substations with the following traits: 71 For DVVC O&M expenses, such as updating site-specific substation operations documents (Substation Standard Instructions) and PCC inspections, please refer to SCE-02, Vol. 10, Grid Modernization. 72 SCE s 2012 General Rate Case, Information Technology and Business Integration (IT&BI) Vol. 3, Capitalized Software. 73 Volt-ampere reactive power (VAR) is the unit used to measure reactive power in alternating current electric systems. Because alternating current systems have varying voltage, these systems must vary the current with the voltage to maintain stability. VARs measure the lead or lag between synchronization of voltage and current. 74 Average cost was derived using constant dollars for the 2016 recorded unit cost and nominal dollars for future years; WP SCE-02 Vol. 11, pp (Capacitor Automation and DVVC Workpapers). 48

50 No active voltage regulation devices (e.g., load tap changers, line voltage regulators, and field voltage regulators), other than capacitors, because these devices do not interact with DVVC; Highly loaded; Feeder circuits which are at or near loading limits; Forecast to have substantial distributed generation penetration; Possessing the most modern substation automation capabilities; Serve temperature-sensitive loads; Areas that have radio network capacity; and/or Having the highest level of compatible PCCs. 2. Advanced Outage Detection and Analytics Program a) Capital Forecast Table V-10 Advanced Outage Detection and Analytics Forecast (Nominal $000) Capital Expenditures (Nominal $000) Project No CIT-00-DM-DM ( Outage Management Enhancements) $0 $0 $16,728 $7,796 $6,796 $31,320 Capital Expenditures (Nominal $000) Project No CIT-00-DM-DM (Meter Firmware Enhancements) $0 $0 $2,616 $4,915 $396 $7,927 Capital Expenditures (Nominal $000) Project No CIT-00-DM-DM (Bellwether Management) $0 $0 $800 $2,000 $1,200 $4,000 49

51 50 Workpaper Southern California Edison / 2018 GRC Figure V-8 Advanced Outage Detection & Analytics Recorded /Forecast WBS Element CIT-OO-DM-DM 75 (CPUC-Jurisdictional Constant 2015 and Nominal $000) b) Project Description The Advanced Outage Detection and Analytics program aims to enhance the capabilities of SCE s infrastructure, and utilize the collective data to improve public safety, outage detection, outage notification, response, and work practices. SCE has deployed approximately five million smart meters, with software, firmware, 76 and back-office systems. SCE has identified an opportunity for improvement to the current smart meter system and its operation during power outages. SCE will make improvements in three areas: Outage Management System Capabilities, Firmware enhancements, and identification and maintenance of critical, or bellwether locations. Please see the diagram below. 75 Refer to WP SCE-02 Vol. 11, pp Firmware is a software or set of instructions programmed on a hardware device. 50

52 51 Diagram V-1 Advanced Outage Detection & Analytics Program These enhancements will better identify the size of the outage along with improve the sped to which we notify the customers. Additionally, these enhancements will allow SCE to detect a single phase fault or an energized wire down. These fault conditions potentially represent a serious public safety and fire hazard. System operators would also benefit from knowledge of faults and wire down situations. Outage management capabilities will be improved to allow for single-line fault detection, quick customer notification, and analytics. The current Outage Management System Gateway is a back-office system which receives power outage notifications and power restoration notifications from the smart meters in the field. It then processes those notifications and translates them into a format the Outage Management System can accept and understand. Enhancements performed will allow SCE to process more and/or different information. The enhancements will utilize outage data and field device data to better inform outage decision-making. The enhancement should also leverage all internal and external data and filter the information to identify the outage footprint. SCE can then dispatch a truck more quickly to fix an issue in the field. The desired enhancement will analyze the patterns and relationships of data through analysis and identify affected outage customers, detect the point of failure on our distribution system, and predict potential downstream outages. 51

53 52 Workpaper Southern California Edison / 2018 GRC To further enable these capabilities, SCE will need to implement Meter Firmware enhancements. The firmware is the software that resides within the end point meters and the cell relays. In the current configuration, the end point meters only can send messages during an outage, and have just 15 seconds to communicate during an outage event. Our planned firmware enhancements provide additional capabilities to help make sure that more power exceptions are captured, and also gather and route new and more frequent operational data. SCE will identify and maintain bellwether locations to assist in the outage notification. Out of the 5 million current end point meters, SCE will identify and select approximately 300,000 devices as representative outage data points. These bellwether locations will be in close proximately to a cell relay, and will provide insight into all three phases of power. Using bellwether locations as a solution means that the end point closest to the cell relay has the best possibility for success in communicating information. The bellwether locations will provide information for outage notification and restoration, and will help confirm the actual size and location of an outage. All these enhancements will increase the speed, accuracy, and effectiveness of communicating outage information. c) Need for Project Including Risk Avoided (1) Outage Management Capability Enhancements Enhancements are needed to increase the potential for data collection of the existing smart meters in the field, specifically improving the back office portion of the outage management system, which processes the data obtained from the smart meter in the field. With the enhancements, SCE will gain visibility into certain single phase fault detections that we simply cannot detect today. These fault conditions potentially represent a public safety hazard. Modifying the current outage management capabilities would allow for single phase capabilities in detecting faults and notifying with respect to energized wire down notification. These enhancements will give our operators visibility in seeing faults or outages that we currently cannot detect on the system. SCE also intends to improve the OMS Gateway, so it correlates internal SCE data with external data such as exceptions, alarms, customer management, grid management and work order information. A key additional capability is the ability to perform time based correlations and correlations to analyze electrical connectivity and proximity. Some further improvements includes active 52

54 discovery 77 of voltage and power checks, automated outage identification and grouping, real time updates to Outage Alert Note (OAN) based on changes in grid state and filtering information to reduce false positives. The improvements will allow SCE to quickly identify and confirm an outage foot print. These improvements leverage the bellwether locations, optimizing information and giving SCE a more proactive approach to field conditions by allowing SCE to confirm the actual size and location of an outage; and identify equipment degradation. The proposed enhancements will reduce the impact of outages to our customers. System operators will be able to better prioritize remote switching to reroute power flows; this minimizes the number of customers affected. Troublemen and field crews can be dispatched sooner to further isolate the problem areas through field switching, and can more readily make repairs to restore customer power. The improvements will also support predictive maintenance, asset planning, energy diversion, grid health and load forecasting. In the existing system, notification to our customers is delayed due to business process rules, technical limitations and processing time. The enhancements will separate the customer notification stream from the work management stream. SCE will also revisit the customer notification business rules and processing times to determine if certain of these delays can be removed or reduced. SCE also plans to automate the manual operations that generates the outage alert note. SCE contacted electric utilities across the US and Canada that have achieved best in class customer satisfaction ratings with a goal of identifying best practices for integrating smart meter data, to improve outage communications and speed up how we respond to customer service issues and restore service for our customers. We confirmed that product capabilities and technology varied, but all of the utilities shared our objective of faster and more accurate communications and responses through better use of smart meter data. As speed and quality often compete for priority, several of these utilities focused their efforts on integrating multiple data sources to improve the quality of the outage information passed to their communications and outage management systems. These same utilities have been able to automate some dispatching decisions after improving the capabilities of their smart meters and back office systems. Many of these utilities were also early 77 The system will automatically check smart meters to for status of power and voltage to help determine the outage area. This is a proactive monitoring of the system instead of waiting for the smart meter to send information. 53

55 54 Workpaper Southern California Edison / 2018 GRC adopters of smart meters, and like SCE have a vested interest in getting more capability from our substantial spend. However, the technology market regarding smart meter integration is relatively immature. Unlike the smart phone industry, our vendors do not have turn-key solutions that readily work across the variety of systems and hardware in place at utilities. Improving in this area will require investments on behalf of our customers. (2) Firmware Enhancements Current meter firmware works well during steady state conditions, but has several limitations during power outages. In the current configuration, the end point meters have just 15 seconds to communicate during an outage; and only meters that are actually losing power send messages. During an outage, SCE needs greater firmware capabilities to help improve the probability of messages reaching a cell relay. 78 The firmware enhancements are also needed to provide additional capabilities to gather and route information during steady state conditions. Such additional information includes battery status, more frequent voltage measurements, tampering data, etc. Capturing this information gives SCE insight to condition changes in the field. (3) Bellwether Management Bellwether Management is a capability that identifies power outages from a set of representative smart meters, which are precisely mapped to the electrical grid. Bellwether Management is needed because today SCE does not have the electrical phase connectivity information associated with the end point meters identified in the system. SCE will be selecting some existing meters and cell relays and will be identifying them as bellwethers. If the bellwether is an end point meter, it will be in close proximity to a cell relay. An electric phase will be identified with each bellwether and these smart meters will be deemed as reliable data points to signal the beginning and end of an outage. SCE can prioritize messages from these bellwether devices during an outage to obtain voltage and phase status more rapidly. This phase association provides SCE better understanding of restoration and helps identify nested outages. 78 A cell relay is a communication device that collects metering data from the smart meters and sends that data to the back office system. 54

56 (4) Benefits These enhancements yield the following benefits: Public Safety: The SCE electrical system experiences several thousand 911 and Wire Down calls each year. This poses a potentially serious public safety and wild fire risk. Due to technological limitations in our current protection systems and supervisory control and data acquisition (SCADA) equipment, SCE cannot detect a subset of high impedance faults. With these fault conditions, wires may fall within reach of the public while remaining energized, posing a risk of electrocution, fire ignition and property damage. Often, our first indication of these fault conditions come from our field workers, first responder organizations, or the general public. High impedance faults and wires down conditions pose a risk until a qualified first responder can secure the scene and properly identify and mitigate the hazard. This often takes longer than one hour from the time of the first call. Utilizing SCE s methodology, we have been able to identify these conditions after the event with historical smart meter data. By implementing changes to our systems, we can identify these conditions closer to real time, along with the approximate location, decreasing the time the public is exposed to these hazards. Outage Detection & Response: much of our outage response is triggered by customer calls and SCADA alarms. Although smart meters reliably send power outage notifications and power restoration notifications (PONs and PRNs), the nature of the smart meter network and associated systems limit the number of PONs/PRNs received by the outage management gateway. In outages affecting larger numbers of customers, but smaller than those detected by our SCADA systems, we find that we often need to rely on customer calls to better define the boundaries of our outages and scope of restoration work. Smart meters send a PON/PRN during planned work and unplanned work. The enhancements should filter PONs due to both planned work (such as a meter exchange) and unplanned work (such as changes initiated by a customer s electrician). Overall, the proposed system enhancements will maximize the number of valid PONs and PRNs passed through the network, while introducing new data sources and applying more advanced capabilities, to more quickly respond to an outage event. Customer Notification: Currently SCE has several means of keeping customers and stakeholders informed about power outages in our service territory. Our website, mobile apps, outbound communications and call centers all rely on the timeliness of information delivered 55

57 56 Workpaper Southern California Edison / 2018 GRC through various systems and aggregated in the Automated Outage Communication application. With recent system improvements, SCE has reduced the time lag of publishing initial outage notifications to our customers. SCE recognizes our regulators and customers expectations for timeliness are rapidly increasing. SCE also recognize that usually, the smart meter outage event is received before a customer calls the contact center. The system enhancements are targeting a much faster initial publication speed. This should improve our service to customers by providing information more quickly to both SCE and customers during an outage. Work Practices: Our operators and dispatchers need to interpret calls, alarms, radio traffic, smart meter PONs/PRNs and utilize the outage management system to create Outage Alert Notes (OANs). The OAN can then be assigned to our Troublemen or Field Crews for resolution. OANs also trigger updates to our Outage Map and other customer notification channels. During storms and major electrical disruptions, substantial traffic may lead to procedural errors, reduce situational awareness for operators and slow the outage management system. This results in miscommunication to customers and inefficient prioritization in our restoration activities. This project helps reduce procedural errors by automating some of the Outage Alert Note creation. Data captured by smart meters enable new diagnostic capabilities such as asset management, system health, and load flow analytics. This project seeks to bring new alarms and data currently not retrieved or only retrieved once per day, to near real-time capabilities. d) Scope and Cost Forecast 79 (1) Outage Management Capability Enhancements There will be several improvements to the outage management capabilities from 2018 through 2020, for a total cost of $31 million. The most urgent enhancement to the OMS gateway is single fault detection. SCE must enhance the system to handle voltage exceptions and enhance DMS to accept an "open circuit breaker" command. This will isolate a potential wire down until a field crew can inspect the situation. SCE estimated the costs for these enhancements using labor estimates for both SCE employees and contract employees. The planning and design for the rule changes is expected by The build, test, and deployment should occur by The final testing and acceptance is planned for SCE provides additional detail with respect to the cost estimates and deployment of assets in WP SCE-02 Vol. 11, pp (Advanced Outage Detection Workpapers). 56

58 Enhancement for early customer notifications creates additional changes within the system. There is also a need to shorten the outage communication processing time. Using trigger-based processing to approach real-time communications will improve the speed in notifying our customers on the size and nature of an outage. The cost estimate includes SCE labor hours, contract hours, and additional computer equipment and memory for decreasing system processing time. We anticipate planning and designing the customer notification system changes in SCE plans to build, test, and deploy by 2019, with a labor cost of approximately $ million for 2018 and SCE plans to purchase, install, and start using the additional equipment in The hardware associated with this sub-project includes purchasing and installing many high-capacity, low-cost distributed database servers for parallel data processing and associated equipment. This includes equipment mounting racks, power distribution units, data cabling and remote monitoring equipment. The reduction to the outage communication processing time is expected to be completed at the same time of the new equipment in The final testing and acceptance of both analytics, software and equipment is expected in 2020 for the remaining cost of $6.8 million. SCE seeks to implement several improvements including, but not limited to time-based correlations, correlations to analyze location proximity, and correlations to analyze electrical connectivity and proximity. By 2019, SCE plans to integrate with back-office systems, such as Consolidated Geographic Information System (CGIS), grid management systems, work management and customer management. By 2020, the enhancements will include a new user interface. By 2020, the capabilities includes active discovery of voltage & power checks, automated outage identification and grouping, real time updates to OAN based on changes in grid state, and filtering of information to reduce false positives. To determine the cost estimate to improve the outage management capabilities, SCE used two methodologies. SCE reviewed and used as a guide the cost estimates from DMS and EMS software enhancements. These two enhancements were approximately $20 million to $30 million. The level of effort, scope and cost for the enhancement would be comparable to these two software enhancements. SCE also performed a second method for cost estimating based on labor hours for SCE and contract labor and equipment. This cost estimate was $25 million, which approximated the same value range as the first methodology approach. 57

59 58 Workpaper Southern California Edison / 2018 GRC (2) Firmware Enhancements SCE anticipates $7.9 million for the firmware enhancements. SCE expects to partner with the current meter vendor, as there is already a significant investment of five million meters and cell relays using firmware from the current vendor. Partnering with the vendor will start in 2016; we will create and prioritize the various firmware enhancements in The vendor will then develop the software in the 2017 timeframe, with expected delivery of the firmware by the end of the first quarter of Testing the firmware is expected to take at least one year. This effort will start in the first quarter of 2018 and end in or around the first quarter of We plan to actually deploy the firmware and upgrade firmware at the endpoint meters and cell relays by the second quarter of The labor spending for the firmware enhancements through the end of 2019 is approximately $7.5 million (covering both SCE labor and contract labor). The firmware costs are associated with developing specifications, designing communications algorithms and logic, and writing computer code, testing new features, and undertaking regression testing of existing capabilities for meter and cell relay firmware. This also includes Network Management System enhancements which will send, receive and act on new messages from the new meter firmware. We estimated the firmware cost by calculating labor hours needed from full-time employees and contract employees to gather requirements, rank the requirements, for the vendor to develop and deliver the firmware, and for SCE to test the firmware and deploy to help ensure the firmware is operable within the meters and cell relays. (3) Bellwether Management SCE will be selecting some existing meters and cell relays selecting and will identifying them as bellwethers. This effort will involve identifying those smart meters, capturing their phase in a database, integrating the database with other systems. The scope for Bellwether Management is approximately 300,000 meters and/or cell relays for a cost of $4 million. The identification of the bellwether locations will begin in 2017 and SCE expects to have the information integrated into databases and other systems by It was estimated that 70% of the analysis required for the identification and classification of bellwethers can be performed by the SCE workforce and contract labor in the office environment, with the remaining 30% requiring field verification. SCE anticipates identifying and maintaining approximately 30% of the devices by 2018 at a cost of $0.8 million. SCE plans to identify and maintain 80% of the devices by 2019 at a cost of $2 million, and the remaining devices by 2020 at a cost of $1.2 million. 58

60 We determined the cost basis using SCE labor and contract labor. There will be research needed to identify the A, B, or C phase associated with specific smart meters. SCE is assuming it can leverage desktop analysis for a majority of the work, rather than relying on actually performing field walk-downs of meters and/or cell relays to confirm phase information for these devices. 59

61 60 Workpaper Southern California Edison / 2018 GRC A. GRC Account SUMMARY OF GRC ACCOUNTS Figure VI-9 Summary of GRC Account Recorded and Adjusted /Forecast (Total Company Constant 2015 $000) $6,000 $5,000 $4,000 $3,000 $2,000 $1,000 $ Recorded Forecast Grid Advancement - Transmission System Labor $2,938 $2,539 $2,302 $1,945 $1,610 $1,610 $1,610 $1,610 Non-Labor $2,098 $493 $480 $769 $988 $988 $988 $988 Sub- Total $5,036 $3,033 $2,782 $2,714 $2,598 $2,598 $2,598 $2,598 Total Labor $2,938 $2,539 $2,302 $1,945 $1,610 $1,610 $1,610 $1,610 Non-Labor $2,098 $493 $480 $769 $988 $988 $988 $988 Total Expenses $5,036 $3,033 $2,782 $2,714 $2,598 $2,598 $2,598 $2,598 60

62 61 1 B. GRC Account Figure VI-10 Summary of GRC Account Recorded and Adjusted /Forecast (Total Company Constant 2015 $000) $16,000 $14,000 $12,000 $10,000 $8,000 $6,000 $4,000 $2,000 $ Recorded Forecast Grid Advancement - Distribution System Labor $7,705 $7,553 $6,928 $7,206 $8,155 $8,155 $8,155 $8,155 Non-Labor $6,069 $4,722 $5,062 $5,397 $5,162 $5,162 $5,162 $5,162 Sub- Total $13,775 $12,275 $11,990 $12,603 $13,317 $13,317 $13,317 $13,317 Advanced Outage Notification Project Labor $ $ $ $ $ $ $ $295 Non-Labor $ $ $ $ $ $ $ $295 Sub- Total $ $ $ $ $ $ $ $590 Total Labor $7,705 $7,553 $6,928 $7,206 $8,155 $8,155 $8,155 $8,450 Non-Labor $6,069 $4,722 $5,062 $5,397 $5,162 $5,162 $5,162 $5,457 Total Expenses $13,775 $12,275 $11,990 $12,603 $13,317 $13,317 $13,317 $13,907 61

63 2018 General Rate Case Workpapers SCE-02, Vol. 11 DOCUMENT PAGE(S) 2015 O&M Request Authorized Recorded Detail Capital Request Authorized Recorded Detail 2 GRC Account Transmission Grid Technology 3-16 GRC Account Distribution Grid Technology WP SCE-02 T&D-Vol. 11-Advanced Technology Laboratories Workpapers AT Technical Testing Facility Survey w BLINDED Responses WP SCE-02 T&D-Vol. 11-Advanced Technology Laboratories WP SCE02 T&D Vol. 11-Advanced Technologies Workpapers, EDEF: Spread Spectrum Time Domain Reflectometry for Fault Detecting in an Electricity Distribution System Phase 2A Extension, Final Report WP SCE-02 T&D Vol. 11-Energy Storage Forecast Pilot Workpapers WP SCE-02 T&D Vol. 11-Capacitor Automation and DVVC Workpapers Final TP&D Report Distribution Automation & DSEEP Support WP SCE-02 T&D Vol. 11-Advanced Outage Detection & Analytics Forecast CET-OT-OT-AT , Advanced Technology Energy Storage Deployment 146 CET-OT-OT-AT , Advanced Technology Electric Vehicle Testing Center (EVTC) 147 CET-OT-OT-AT , Advanced Technology Equipment Demonstration & Evaluation Facility (EDEF) 148 CIT-00-DM-DM , Capitalized Software Bellwether Management 149 CIT-00-DM-DM , Capitalized Software Meter Firmware Enhancements 150 CIT-00-DM-DM , Capitalized Software CONI 151 CET-PD-LG-CV-MTW Capacitor Automation 152 CET-PD-LG-CV-MTE Capacitor Automation 153

64 1 O&MWaterfallChartDetail,SCE02,Vol GRC 2015GRC Exhibit Account ForecastActivity WaterfallGrouping $2012 $ Request Authorized Request Authorized Recorded SCE02,Vol Consultants GridAdvancement SCE02,Vol GridAdvancementDistributionSystem GridAdvancement 11,351 11,351 11,936 11,936 13,317 (1,381) SCE02,Vol GridAdvancementTransmissionSystem GridAdvancement 2,845 2,845 3,024 3,024 2, SCE02,Vol InformationTechnology/CorporateRealEstateChargebacks, GridAdvancement Variance

65 2 Workpaper Southern California Edison / 2018 GRC Grid Tech. Authorized vs. Recorded Workpaper - $Millions Program Waterfall Chart Category 2015 Requested 2015 Authorized 2015 Recorded Rec.vs Auth. Var. Consrvtn Voltage Reg Consrvtn Voltage Reg Advanced Technology Advanced Technology Energy Storage Initiative Energy Storage Initiative Total $17 $10 $12 $2

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105 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Pleaseanswerthefollowingquestionsinreferencetoyourcurrentfacilities'technicaltestabilities.NOTE:Thesequestionsareprefacedwiththefollowingstipulationsinorderfora"Yes"tobeavalidresponse: 1.Thetestfacilitydoesnotneedtoundergosignificantremodelingtoaccommodatetestingofsuchtechnologyoriftestfacilitycanmeettestcapability,butrequiresminorretooloffacilityortestapparatusto accommodatetestingofsuchtechnology,theretooltimewilltakelessthanoneweektocomplete. 2.Testfacilitycurrentlyhasallnecessaryequipmenttoconducttestingwithouthavingtoprocuretestequipmentbyeitherpurchasingorrent/leaseagreementstomeettestingcapabilities. 3.Testfacilityhasqualifiedpersonnelonstafftoconductsaidtests. 4.DatathatresultsfromalltestsmustbecollectedfromcalibratedNISTtraceableequipment(whereapplicable)andmustbeassessedusingstandardandacceptedpracticesofuncertaintyanalysis. SCEResponse Respondent01 SurveyQuestions Yes No Comments Yes No Comments Controls 1 Doesyourfacilitycurrentlyhavethecapabilitytorunrealtimesimulationofdistributionfeeders? Yes Wehavethreesimulatorsandareintheprocessofobtainingafourth. OPALRT;GridLABD;VOLTTRON Allthreesimulatorscanperformopenorclosedloopviaindustrystandardcommunication 2 Canyourfacilityperformhardwareandsoftwareintheloop(closedandopen)testing? Yes protocolsorviaanalogvoltagesignals. alltoolsarecapableofhil;opalrtmeetsmostindustrystandards,volttronmeetsmost buildingautomationindustrystandards,gridlabdisnotbasedonindustrystandards 3 Isyourfacilitycurrentlycapableoftestingcontrolssystemsusingattenuatedradiocommunicationhardware? Yes Thefacilitycurrentlyhostsseveralradioswithsignalattenuatorsconnectedtoeachradio. N/A 4 Doesyourfacilitycurrentlyownandoperateamplifiertestsetsfordrivinghardwarewithsecondaryvoltage andcurrentsignals? Yes Thefacilityhosts2Dobletestsetswhichcangenerate6voltagesand6currentseach. WehavevoltageandcurrentamplifiersfromOPALRTwiththecapacitytogenerate amplifiedsignalsfor16channelsofvoltage(upto150vrms)and16channelsofcurrent(upto 2ARMS). TheDobletestsetshaveananalogvoltageinputfordrivingthetestsets.Thesimulatorscan Yes producetherequiredvoltageinputs. ThevoltageandcurrentamplifiersaretightlyintegratedwiththeOPALRTsimulator'sanalog outputsandcanbedrivenbythesignalsfromtherealtimesimulation. IfyestoQ.4,canthetestsetsbedrivenbythesimulatorsinthefacility? 6 Isyourfacilityintegratedwithsystemsinotherfacilities/labssuchascybersecurity,substationautomation, fieldautomation,fieldmessagebus,andenterprisebusarchitecture? Yes Thefacilityisconnectedtoalllabfacilitiesandhasperformedtestswhichinteractedwith enterprisebusarchitecture. Multipletestfacilitiesincybersecurityandsubstationautomationsitonacommon infrastructureandhavebeentestedforinteroperability DistributionAutomation Wehavetheabilitytofullytestthe61850Goosemessagingstack. WehavetheabilitytotestIEC61850capabilitiesusingourOpalRTandTriangleMicroworks Asanexample,thisfacilitycantestRemoteIntelligentSwitchwithRFradioandadvanced Tools.TheOPALRTsimulatorthatwehavecurrentlysupportsIEC61850GOOSE&SV. 7 Whatareyourfacility'sIEC61850testingcapabilitieswithregardtoDistributionAutomationsystems? controllercapableofhandlingmultiplecommunicationprotocol DNP3,IEC6185.Capableof BesidesIEC61850,thesimulatorsupportsIEEEC37.118,DNP3,ModbusTCP.Wehave distributedintelligenceandcentralintelligence.capableofhandlinglowspeedandhigh workedwithtmwinpasteffortstoperformdeveloperconformanceandinteroperability speedcommunication.capableofvariouslogic/algorithmprogramming. testingofiec62351.wealsohaveiec61850capabledevicesfromavarietyofvendors. 8 Isyourfacilitycurrentlycapableoftestingintegrationofnextgenerationsubstationanddistribution automationsystems? Yes Thesimulatorscanrunarealtimemodelofnextgencommunicationanddistribution automationscheme.thesimulatorsalsosimulateactualfaultconditions. Thesimulatorscanrunarealtimemodelofnextgencommunicationanddistribution automationscheme.thesimulatorsalsosimulateactualfaultconditions.simulatorsareable toincorporatelargescaleders(andcontrols). 9 IsyourfacilitycurrentlyequippedwithRealTimeDigitalSimulators(RTDS)? Yes Accesstothesimulatorsisprovidedthroughthefacility'snetwork. OPALRT Whatareyourfacility'scurrenttestingcapabilitiesforbroadbandwirelessnetworkintegrationofdistribution automationssystems? Ourfacilitycurrentlyhastheinfrastructuretofullytestnextgenerationbroadbandwireless systemsthroughtheuseofvariousnetworktesttoolssuchasiperfandowamp.weare Wehavetheabilitytosimulatecharactersiticsofwirelesscommunicationwhenusingwired 10 alsoequippedtofullytesttheendtoendcapabilitiesofanynextgencommunicationsystem networksbutwedon'tcurrentlysupportwirelessbroadbandcommunication. throughtheuseofexistingandnextgendistributionautomationdevices. DistributedEnergyResources Whatareyourfacility'scapabilitiesfortestingandevaluatingthefollowing? UtilizinggridandPVsimulatorswehavetheabilitytorunvariousvoltage,frequency,and Smart(SolarPV)Inverters? None. environmentalconditionstoreplicaterealworldscenarios. 11 WehavemultiplecommercialrooftopA/Cunitsforefficiencytesting,however,theyarenot CommercialrooftopA/Cunits? VoltageflickerandinrushcurrentconditionsarecreatedtoevaluateACunits. currentlyconnectedtothegridtestfacility. DuctlessresidentialA/Cunitwithvariablefrequencydrives(VFD)? Wecanreplicatevariousgridconditionssuchasvoltageflickerandinrushcurrent. None. Secondaryvoltageregulationdevices? Wehavetheabilitytosimulatedifferentpowerfactorconditionsandvarysystemvoltages. None. 12 Doesyourfacilitycurrentlyhavetheabilitytoenergizeutilityandcustomerdevicesinordertooperatethem inacontrolledenvironment,isolatedfromtheelectricgrid? 13 IfyestoQ.12,doesyourfacilityhavethecapabilitytosubjectthesedevicestoabnormalvoltageand/or frequencytransientsthatarerepresentativeofactualeventsthatcanoccurontheelectricgridtounderstand thedeviceresponseduringsuchevents? Doesyourfacilityhavetheabilitytogeneratearbitraryandtransientwaveformswiththeprogrammable powersupplieswhichwouldallowtheassessmentof: Yes Yes Utilizingagridsimulator,PVsimulators,andloadbankswecanreplicaterealworldgrid conditionsusingisolatedtestpanels. Utilizingagridsimulator,PVsimulators,andloadbankswecanreplicaterealworldgrid conditionsusingisolatedtestpanels. TheOPALRTrealtimesimulatoristightlyinterfacedtovoltageandcurrentamplifiersthat candrivesignalsupto150vand2armsforfrequenciesbetween30hzto1khz.additionally, anomicron256programmablemultiphasesignalsourceisusedforrelaytestingandis capableofmuchofwhat'slistedhere. PVinvertervoltage/frequencyprotection? Yes UsinggridandPVsimulatorsvoltagedipsandswellsarecreatedforevaluationofdevices. 14 Ridethroughcharacteristics,stabilityduringoscillations? Yes UsinggridandPVsimulatorsvoltagedipsandswellsarecreatedforevaluationofdevices. Antiislandingcapabilities? Yes Utilizeloadbankstomatchloadwithinverterbasedgeneration. Agridsimulatorisusedtogeneratevoltageharmonicsandhighresolutionmonitoring Harmonicsgeneration? Yes equipmenttoassessdeviceperformance. Wecancreatefaultsorshortcircuitsviaphasetophaseandphasetogroundsimulationsin Faultcurrentcontribution? Yes anisolatedenvironment. Customizedtestsetupscanbecreatedtointergradeallofthesedevicecapabilitiesdepending Doesyourfacilitycurrentlyhavethefollowingequipmentandcapabilities?Ifyes,whatisthelevelof onthetestingneeds.forexample,invertertestingwouldutilizeallofthesedevicesandair integrationbetweenthesedevices? conditioningtestingwouldnotuseapvsimulator. PVSimulators(ProgrammableDCPowerSupplies)? Yes ThesescenarioscanbemodeledinOPALRTandthecorrespondingsignalscanbegenerated throughtheanalogoutputinterfacingwiththevoltageandcurrentamplifiersmentioned above.additionally,theomicron256sourcecangenerateharmonicsandbeusedforfault currenttestingofrelaysandsimilardevices(withseparatevoltageandcurrentinputs) Programmableirradiance&temperatureprofiles? Yes Yes.OPALRTrealtimesimulator(EMTP,Transientstabilitysimulations)withvoltageand GridSimulators(ProgrammableACPowerSupplies)? Yes currentamplifiers.alsoomicron256source. Yes.Thiscanbedonewiththesamesetupasdescribedaboveforthevoltageandcurrent Voltage&frequencytransientgeneration? Yes 15 rangesforfrequenciesbetween30hzto1khz. Harmonicswaveformgeneration? Yes Omicron256candothesamewithvoltagesupto150Vrmsandcurrentupto75Arms. Arbitrarywaveformgeneration? Yes LoadBanks? Yes Standalone5kWloadbank Programmablepowerfactor? Yes Omicron256multiphasesignalsource,programmablePF. Yes.Thiscanbedonewiththesamesetupsasdescribedaboveforthevoltage,currentand Customwaveshapes? Yes frequencyrangesmentioned. ShortCircuitTestBox? Yes Multiplefaultcombinations(3phgnd,phph,1phgnd,etc.)? Yes Omicron256describedabovecanbeusedforfaulttestingrelays SCE Confidential Page 1

106 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 SCEResponse Respondent01 SurveyQuestions Yes No Comments Yes No Comments GridEdgeSolutions 16 Doesyourfacilitycurrentlyhavetheabilitytosupportsmartgridinitiativesthatrequireradiocommunications testing/evaluationand/orutilizesmartmeterdataandinfrastructure? Yes HANandFAN. 17 Isyourfacilitycurrentlycapableofusingsmartmeterdatatoimproveaccuracyofthemeter/transformer correlationmodel? Yes Smartmeteroutagedataisusedtocorrelatemetertotransformer.Voltagesignature analysisisalsoused. 18 WhatareyourfacilitycapabilitiestotestradiocommunicationforHomeAreaNetwork(HAN)andFieldArea Network(FAN)andothertelecomfordistributionfieldequipment? Yes HAN:Sniffers,Zigbeedongles:RainForest,Daintree,MMB,Telegesis.RF:antenna,spectrum analyzer,testharnessforinterference,remotesensorsforcoverage/rssitesting. FAN:Network,Mesh,PttoPt.Throughputandinterferencetesting.Networksecuritytesting. NTPtimeandrecieversensitivity(steppedattenuators) Isyourfacilitycurrentlyequippedwiththefollowing? Signalgeneratorsandanalyzers? Yes Vectorgenerators,spectrumanalyzer,powermeters,andGPStimestandard. ZigBeesignalsensorsanddecoders? Yes See18(above) Testharnesses? Yes QualityLogicSEP2.0harness. 19 Powerlinecarriersignalgenerator? Yes PLCtestsystemfromNESTA/AEP.Permanentlabinstallationforinterferencetesting. RadiosignalisolationboxesandFaradayCage? Yes FullsizeFaradaycage.FANtestingwithRFenclosures. Smartmetersandcellrelays? Yes Livelabreferencesamplesatproductionrevision. GarageoftheFuture Doesyourfacilitycurrentlyoperatewiththefollowingequipmentand/orcapabilities? Photovoltaic(PV)simulatorsallowingsimulationofPVorStorage(DC)interactions? Yes PVsimulatorallowingsimulationofPVandStorage. 20 EnergyStorage,ElectricalVehicles(EVs),DCFastCharger,RoofTopPVtoallowdemonstrationand EVSErackallowingtestingoflevel2EVSE's,3.3KWrooftopPVconnectedtoastoragedevice. Yes evaluationofcommunicationsandcontrolsintegration? Alldevicesarenetworkedallowingfordemonstrationofcommunicationandcontrols. ExternalandInternalNetworkInterfacesForinterfacingwithcontrolssystems,internetbasedentities, andinternalequipment? 21 Doesyourfacilitycurrentlyhavethecapabilitytoconductbothopenandclosedlooptestinginasandbox typeenvironment? Yes Openinternetaccessandfacilitynetworkaccess. Yes WiththePVsimulatorandgirdsimulatorwehavetheabilitytocreatesandboxtypetest environments. Gridsimulatorsallowustoconduct"sandbox"tests.HIL(OpalRT)allowsfortestingof specificapplicationsandaconnectiontogridlabdallowsforscalability. 22 IfyestoQ.21,isyourfacilityabletosimulateandevaluateavirtuallyunlimitedsetofusecasesinsafeand controlledconditions? DistributionGridAnalytics Yes AllusecasesthatpertaintocustomerownedDER's. Usecasesarevirtuallyunlimited. 23 Doesyourfacilitycurrentlyhavetheabilitytoevaluateandutilizeseveralmodelingtoolstodevelop distributioncircuitmodels? Yes 24 IfyestoQ.23,canthesemodelsshowaccuratedynamicandsteadystatesimulationsrepresentingbeyondthe meterloadsleveragingsmartmeterdata? Yes Wecancreatedetailedbeyondthemeterloadmodelsforresidentialcustomersandload profilesforcommercialcustomers.thesemodelsareusedtostudythedynamicandsteady stateconditions.wealsoperformdynamicsimulations. GridLABDincorporatesbehindthemeterloadmodelingthatcanbecalibratedtoAMIdata. 25 Doesyourfacilitycurrentlyhavetheabilitytoanalyzeandvisualizetestdataandresultstodevelop integrationstrategiesandinformfielddeploymentofcontrolequipment,energystorageandotherdevices? Yes Weanalyzeandvisualizedatafromtestsandbulkdatafromthegrid. Wehaveintegratedtoolstoanalyzeandvisualizetestdata. 26 Canyourfacilitycurrentlyevaluatedifferentsoftwaretoolsandsolutionsthatprovidevisualizationofpower distributionsystems? Yes Wecanevaluatemanysoftwaretoolsinasecuredtestenvironmentwithoutaffectingthe grid. Althoughsomemodificationsareneededtoaligndatasetstodataformatrequirementsof differenttools. 27 Doesyourfacilitycurrentlyhavetheabilitytodevelop/evaluatenewdatabasestructuresandmathematical methodologiessuchasdimensionreductiontohandledistributeddata? Yes Wehavetheabilitytotestanddevelopnewdatabasestructures. Andwehaveastrongteamindataanalyticsresearch. Canyourfacilitycurrentlyconducttimeseriesanalysistodynamicallycalculatethedistributedenergy 28 resource(der)hostingcapacityforanygivennodewithinthedistributionandtransmissionsystemforany Yes Wehavetheabilitytoperformtimeseriesanalysis. Distributiononly. houroftheday? PowerSystems 29 Doesyourfacilitycurrentlyhavetheabilitytoconducthardwareintheloopcontrolsystemtesting,protective relaytesting,wideareaprotectionandcontroltesting? 30 Doesyourfacilitycurrentlyhavetheabilitytoevaluatesmartgriddevelopmentforinclusioninanelectrical grid? 31 Doesyourfacilitycurrentlyhavetheabilitytorunlargescalerealtimesimulationsutilizingcontrolsystemand relaycommunicationsequipment? SubstationAutomation Doesyourfacilitycurrentlyhaveaplatformtotestintegrationofinservicelegacyproprietarysubstation 32 automationsystemsbasedonmodbusplusandmodbusprotocolswithnewiec61850openstandards systems? 33 Doesyourfacilitycurrentlyhavedirectconnectivitytoatestenergymanagementsystemfortestingand integratingnewsupervisorycontrolanddataacquisition(scada)systems? Yes Yes Yes Yes Yes Thesimulatorscandrivealowlevelrelayinput,orcandriveaDobletestsetforasecondary voltageandcurrentinput.severaltestshavebeenconductedusingrelaystoevaluateandtest wideareaprotectiontechniques. Smartgridequipmentcanbetested,evaluated,andcoordinatedusinghardwareintheloop simulations. Thefullbulksystemmodelcanbesimulatedusingrealtimesimulationsenvironmentthat combinebothcontrolsandprotectionhardwareaswellasthetransientmodelsofthesystem components. Thisfacilityhasallnecessaryequipmentandpersonneltoperformintegrationtestusing, ModbusPlus,ModbusTCP,ModbusRTU,andallprotocolsusedinIEC ThisfacilityhascommunicationstoatestEMSsystem.Systemtestcanbeperformedonboth Serian,andEthernetChannels. Yestoall. SmartgridapplicationscanbetestedinsmallscaleHILorlargescalesimulation. LargescalerealtimesimulationscanbeperformedviaGridLABD;incorporatingaco simulationengine,thiscanreachthescaleof~1,000circuits. WehavethecapabilitytotestModbusandIEC61850withsupportingdevices,software,and expertise.welacksupportformodbusplus. WecurrentlyhaveaccesstoanAlstomEMS&DMSforintegrationintotestcases. 34 Doesyourfacilitycurrentlyhaveaninhouserealtimedigitalsimulatorsystemfortestingofsubstation protectionandautomationfunctionstofullyvetandtestnextgenerationsubstationautomationsystems? Yes WecurrentlyuserealtimedigitalsimulatorsandavarietyofI/Omodulesdedicatedfor substationautomationsystemtesting. WehaveanOPALRTrealtimepowersystemsimulatorcoupledwithvoltageandpower amplifiercardsforhiltesting. 35 Doesyourfacilitycurrentlyhavetheabilitytomimicalargesubstation(upto70racks)fortestingofgrid modernizationequipment? No WecanmodelalargesubstationwithintheOPALRTwithsubsetsofrealequipmentwhere necessary. 43 SCE Confidential Page 2

107 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 SCEResponse Respondent01 SurveyQuestions Yes No Comments Yes No Comments EquipmentDemonstration&EvaluationFacility Doyoucurrentlyhaveahighvoltagedistributioncircuit(12kV35kV)facilitydedicatedtotestingnew equipment?ifyes,pleaseanswerthefollowing: Yes Doesthisfacilityfeedanycustomers? No Thiscircuitdoesnotfeedanycustomers. Thecircuitisfedfromadedicatedcircuitbrakerfromasubstationwhichfeedsother12kV Isthisfacilityintegratedwithotherdistributioncircuitsfedfromthesourcesubstation? Yes circuits. Isthisfacilitycapableofperformingintegrationtestingthatwouldincluderadioandcommunication Yes systemsusedforcircuitautomationandmonitoring? Canthisfacilityperformsimultaneoustestingofupto10automatedfaultinterruptingdeviceincluding Circuithasbothoverheadandundergroundsectionstoenabledifferenttestconfigurations Yes overhead,padmountandunderground(insideavault)? andscenarios,multipletestpadsandanundergroundvault. Facilityisequippedwithfaultpadsandaconfigurableresistorcabinetdedicatedtofault Canthisfacilityperformsimulationofvariousfaultmagnitudeandconditionson12kVdistributioncircuits? Yes testing. Doesthisfacilityhaveapowersystemsimulatorwithhardwareinthelooptestingcapability? Yes Doesthisfacilityhavethecapabilitytotestamicrogridwithdevicesthatallowforreconfigurationsuchas 36 loadbanks,gridsimulator,smartinverters,batterystorageandvoltageregulationdevices(capacitor, Yes voltageregulator,etc.)at12kv? Doesthisfacilityhavethecapabilitytoconfiguretestforoverheadandundergroundconductorsora Yes Thecircuitconsistsofbothoverheadandundergroundportions. combinationofboth? Canthisfacilityperformhighimpedancefaulttestingonanenergized12kVcircuitwithacombinationof Yes Wehaveperformedseveral12kVhighimpedancefaulttestsatthisfacility. overheadconductorandundergroundcableswithinthenext2months? Canthisfacilitylimitthefaultcurrenttoanyspecificrange? Yes Aresistorcabinetcanbeusedtolimitcurrentduringfaulttesting. Doesthisfacilityhavethecapabilityofintegrating2MWbatterystoragethatcanactbothasasourceand Yes load? Ifyestothepreviousquestion,isthefacilityconfiguredtoallowthe2MWbatterytoconnecttovarious locationsonthe12kvcircuitbyperformingcircuitswitchingusing12kvdistributionswitches(forvarious Yes testscenarios)? Oncecontrolroomconstructioniscomplete,simulatordeviceswillbeincorporatedand Doesthisfacilitycurrentlyhaveanintegratedgridsimulatordevices? No connectedtocircuit. Ifyestothepreviousquestion,doesthisfacilitycurrentlyoperatea1MVA@12kVgridsimulatorwhere voltage,frequency,realandreactivepower(utilityandcustomerload)canbesimulatedandadjustedto replicatefieldevents? Canthisfacilitytestshortcircuitimpactat12kVforDistributedEnergyResources(DER)? Yes CanthisfacilitytestvoltageimpactsonDERswitchingdevices? Yes Doesthisfacilitycurrentlyhaveintegratedsecondary(upto2MVA,withstepuptransformersto12kV) Yes Facilityhasloadbanks(upto2MVA) loadbanks? Doesthisfacilityhaveadataacquisitionsystemwiththeabilitytoprocessanddisplaydata? Yes Doesthisfacilityhaveadedicatedcontrolroomwhereinformationtechnologybackofficesystemsand Controlbuildingisinthefinalstagesofplanningandpermittingwithanexpectedopeningof Yes controlsystemscanbemanaged? Q Doesthisfacilityhavethecapabilitytotestsubstationprocessbus(digitalsubstation)? Yes 37 Doyouhaveafacilitycapableofmonitoringtestcircuitsandthetestsperformedusinganexistingdistribution managementsystem(dms)? Yes 38 Doyouhaveafacilitycapabilityofsimulatingvariouscircuitlengths? Yes Thisispossiblebyutilizingdifferentswitchingproceduresandcircuitconfigurations. 39 Doyouhaveafacilitycapabilityofsimulatingdifferentcircuitconfigurations(loop,radial,network)? Yes Thisispossiblebyutilizingdifferentswitchingproceduresandcircuitconfigurations. EnergyStorage(BatteryProfiling,Testing,andEvaluationCapabilities) 40 Doesyourfacilityhavethecapabilitytotestlargebatteriessystemswithmaximumratingsof900VDC,1000A DC,and250kWinlargetemperaturecontrolledenvironments(upto870cubicft,between45 Cand70 C)? Yes x Organization'doesnotcurrentlyhavethecapabilitytotestenergystoragesystemswiththese requirements 41 Whatisthetotalnumberofindividualtestsonlargebatteriessystemsthatcanbetestedatanygiventime? Note:thisquestionreferstothenumberofindividualteststhatcanberuninparallel. Fourtestsat900VDC/500ADCortwoat900VDC/1000ADC 42 Doesyourfacilityhavethecapabilitytotestbatteriespackswithmaximumratingsof445VDC,265ADC,and 125kWinlargetemperaturecontrolledenvironments(upto64cubicft,between45 Cand70 C)? Yes Organization'doesnotcurrentlyhavethecapabilitytotestbatterypackswiththese requirements 43 Whatisthetotalnumberofindividualtestsonbatteriespacksthatcanbetestedatanygiventime? 14testsat445V/265A/125kWoruptofourat445V/530A/125kWanduptothreeat 445V/640A/125kW 44 Doesyourfacilityhavethecapabilitytotestbatterycellswithmaximumvoltageof5VDCand400ADCin temperaturecontrolledenvironments(between34 and70 C)? Yes x Organization'routinelytestsindividualcellsintemperaturecontrolledenvironments. 45 Whatisthetotalnumberofbatterycellsthatcanbetestedatanygiventime?Note:thisquestionreferstothe numberofindividualteststhatcanberuninparallel. Twocellsat5VDC/400Aoreightcellsat5V/100A.Anadditional16cellscanbetestedat 5V/10A,orfourat50V/40A. Currentlyinexcessof300channelsthatcantest5V40Asystems,~3testsystemsthatcan handle5v400a. 46 Doesyourfacilityhavethecapabilitytotestacompleteenergystoragesystem(ESS)withmaximumratingsof Yes 480VAC,and250kWandupto140sq.ft.footprintpersystem? DoesyourfacilityhavethecapabilitytotestindividualcriticalcomponentsofanESS? Yes Completeenergystoragesystemshavebeentestedat'Organization'aninterconnectedto buildingandpvresourcesforusecaseanalysis PowerConversionSystems(PCS)? Yes x Organization'hasthecapabilitiestotestPCSatvariouslocationsacrosscampus.BMSand 47 BatteryManagementSystems(BMS)? Yes x ESScontrolandcommunicationinterfaceshavetestedinconjuctionwithfielddeployedESS systems Controlandcommunicationinterface? Yes x DoesyourfacilityhavethecapabilitytoconductgridimpacttestingofESS(e.g.,powerqualityanalysis)? 48 CanyourfacilityconducttestingbyconnectingESS'stothegrid? Yes Facilityhasthenecessarytestbedstoperformgridconnectedtesting. Canyourfacilityconducttestingbyutilizingasimulatedgridthatcanrunprofilesforgriddisturbancesat Yes variousvoltageandphaseconfigurations? ESSsystemshavebeentestedconnectedtoPVandbuildingsbutwhereisolatedfromthe grid.withapproval,gridconnectionispossible. 49 WhatisthetotalnumberofESSthatcanbetestedatanygiventime? Maximumof18systemsand24cells 50 DoesyourfacilityhavethecapabilitytoconductevaluationofPhotovoltaic(PV)equipmentsuchasPVarrays, andpvinverters? Yes Yes,'Organization'hasa128kWPVarraywhichhasbeenpreviouslyintegratedwthlarger scale(125kw/500kwhr)ess 44 SCE Confidential Page 3

108 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 SCEResponse Respondent01 SurveyQuestions Yes No Comments Yes No Comments ElectricTransportation Doesyourfacilityhavethecapabilitytoconductfueleconomyandemissionstestingoflightdutyvehicles ThefacilityconductsfueleconomyandemissionslightdutyvehiclesasdefinedbyDOTwith2 Yes accordingtofederalstandards? onboardemissionstestingsystems. Facilityhasexperiencewithtestingprototypeandproductionmodelvehicleswith ConventionalICEVehicles? Yes conventionalinternalcombustionenginespowerunits. Facilityhasexperiencewithtestingprototypeandproductionmodelvehicleswithfullbattery 51 ElectricVehicles? Yes electricpowerunits. Facilityhasexperiencewithtestingprototypeandproductionmodelvehicleswithhybrid HybridElectricVehicles? Yes batteryiceandhydrogenbatterypowerunitvehicles. Onroadonly.Experiencewithtestingvehicleswithhydrogenandcompressednaturalgas GaseousFueledVehicles? Yes powerunitsbutlacksgarageanddynamometergaseousfuelfacilities Doesyourfacilityhavethecapabilitytoconductheavydutyenginetestingaccordingtofederalstandards? No Thefacilityisnotequippedwithanenginetestdynamometer. Fueleconomytesting? No Emissions? No HybridElectricDrives? No GaseousFuelEngines? No Doesyourfacilityhavethecapabilitytoconductfueleconomyandemissionstestingofheavydutyvehicles ThefacilityconductsfueleconomyandemissionsheavydutyvehiclesasdefinedbyDOTwith Yes accordingtofederalstandards? 2onboardemissionstestingsystems. Lighttomediumdutyonly.Facilityhasonsitedynamometerwith2and4wheeldrive Ondynamometer? No capabilitywithamaximumgvwrof14,000lbs. FacilityhasPEMSportableemissionsmeasurementsystemsandexperiencewithonroadand Onroad? Yes tracktestingofheavydutyvehicles. Facilityhasinstrumentationtocaptureelectricenergyflowsandexperiencewithtesting HybridElectricVehicles? Yes prototypeandproductionmodelvehicleswithhybridbatteryiceandhydrogenbattery powerunitvehicles. Onroadonly.Facilityhasexperiencewithtestingprototypeandproductionmodelvehicles GaseousFuelVehicles? Yes withhydrogenandcompressednaturalgaspowerunits. PEMSemissionstesting? Yes Facilityhas2systemsforPEMStesting. Bagemissionstesting? No Stationaryutilityorothervocationalcycles? Yes Facilityhasexperiencetestingutilitytoolsintypicalutilitylinemandutycycles. DoesyourfacilityhavethecapabilitytotestElectricVehicleSupplyEquipment(EVSE)? Yes FacilityhasDranetzPowerProfilers. SAEJ1772Levels1and2? Yes FacilityhasEVemulators,Evs,andgridsimulators;multiplesitesforlabandfieldevaluation. SAEJ1772Level3AC? Yes Facilityhashighvoltageandhighpowerinstrumentation,gridsimulators. SAEJ1772DCFastChargeComboCCS? Yes Facilityhashighvoltageandhighpowerinstrumentation,gridsimulators. Facilityhasgridsimulators,instrumentation,andexperiencewithbidirectionalpowerEVSE BidirectionalpowerEVSE? Yes testing. AC3phaseEVSE? Yes FacilityhasDranetzPowerProfilers. OverheadconductivepowertransferEVSE? No Fieldtestonly. WirelesspowertransferEVSE? Yes PQandEMF(fieldonly). FastChargeChAdeMO? Yes Facilityhas1siteforChAdeMOfastcharging. Gridsimulationandgridimpacts? Yes FacilityhasgridsimulatorsandSAEJ2894expertise. Doesyourfacilityhavethecapabilitytotestfullpluginelectricvehicle(PEV)chargingsystemsforeffect, Yes efficiency,andpowerquality? 55 SAEJ2894/2? Yes CaliforniaTitle20? Yes Vehicletogridsystems,IEEE1547,UL1741? Yes Doesyourfacilityhavethecapabilitytotestauxiliarypowersystems? Yes Enginegenerators? Yes BatterypowersystemsincludingBMSandcontrols? Yes ACpowerinvertersystems,powerquality,inputoutput? Yes 56 DCDCpowersystems? Yes Hydraulicpowersystems? Yes Powerthermalmanagementsystems? Yes Electricalisolationandpersonnelprotection? Yes HVACsystems? Yes Compressedairstoragesystems? Yes DoesyourfacilityhaveinhouseCFR/EPAspecificationchassisdynamometer? Yes LightDuty? Yes Upto14000lbs.GVWR 57 HeavyDuty? No Upto14000lbs.GVWR Emissionsmeasurement? Yes PEMSportablesystems PEVcharginginfrastructure? Yes ChargingsiteinDynamometer,alllevels. Gaseousfuels? No SCE Confidential Page 4

109 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent02 Respondent03 Respondent04 Yes No Comments Yes No Comments Yes No Comments Feedersizeislimitedafewhundredssinglephasenodes. Goose,DNP3 NONE PVsimulatorsthatcanvaryvoltage,current,frequency,irradiance Poweramplifier,pvsimulators,ac/dcloadscansimulaterealgrid Notsureaboutthisone Mostoftheequipmentinthelabiscompatible AnumberofPVsimulatorsandsmallerscaleprogrammableDCsources. ProgrammableDCsourcesthatcanfollowirradiancetimeseries.Notemperatureprofilesare ViaPVSimulatorsoftwareorexternalcontroller available. Notsureaboutthisone Notsureaboutthisone Notsureaboutthisone singleandthreephase.resistiveandinductive Notsureaboutthisone 46 SCE Confidential Page 5

110 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent02 Respondent03 Respondent04 Yes No Comments Yes No Comments Yes No Comments PIServertosupportabilitytousesmartmeterdataandinfrastructuretostreamthedata(not onradiocommuniations) 47 Notsureaboutthisone Therearelimitationsofcourse Workingonit,notcompletelythereyet Notnecessarilyafunctionused,butpossible Workingonit LimitRTDSto100nodes,Hypersimbasedonthenumberofcoresavailable Notsureaboutthisone OurRTDSisasharedresource.Dist,trans,subetc.canhaveaccessforutilization. (PossiblewithfurtherexpansionofHypersimSystem) SCE Confidential Page 6

111 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent02 Respondent03 Respondent04 Yes No Comments Yes No Comments Yes No Comments Notunderstandingthequestion possible spaceislimited assumingfaultsfromrtdsonly Notsureaboutthisone Notat12kV,butcontrollersetc.yes.VariousVDCandACupto480V v Notsureaboutthisone x (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') (Maybejointlywith'anotherorganization') SCE Confidential Page 7

112 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent02 Respondent03 Respondent04 Yes No Comments Yes No Comments Yes No Comments Notsureaboutthisone Notsureaboutthisone Notsureaboutthisone Notsureaboutthisone 49 SCE Confidential Page 8

113 50 Workpaper Southern California Edison / 2018 GRC SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent05 Respondent06 Yes No Comments Yes No Comments Yes No Comments Respondent07 Yes OurfacilityhasthreeRTDSTechnologiesracks yes RTDSandOPALRT Yes yes RTDSandOPALRT No yes 200Mhz5.8Ghz No yes No yes (3)Omicrontestsetswit(4)voltagesand(8)currentsand(1)Doble+(2)OmicronsatCRC No yes WecandesignandimplementanytestrelatedtoIEC61850perclientrequirements. Bestinclass. Yes yes Yes yes RTDSandOPALRT Wehavealargerangeofequipmentfortestingofwirelessnetworksandhaveusedit extensivelyinourcybersecurityanalysisofgridequipment. BestinClass 'Org'hasthelaboratoriesandequipmenttodesignandimplementawidevarietyoftesting tocustomerrequirements. Wehavetheabilitytoconductbenchtoptestingatvariousvoltagesandfrequencies,aswell WeareabletointerfacePVinvertercontrollersinaHILconfiguration,butnoPHILcapability asenvironmentalandsalt/fogchambers. Potentiallywecouldbasedonclientrequirements. No Potentiallywecouldbasedonclientrequirements. No Potentiallywecouldbasedonclientrequirements. WeareabletointerfacecontrollerswiththeRTDSinaHILconfiguration 'Org'hasa1miledistributionlineenergizableupto4kVisolatedfromtheelectricalgrid. No yes No yes 'Org'hasequipmentthatcanbeutilizedtodesignmostanytestfordestructiveandnon destructiveevaluation. yes Equipmentisjustbeinginstalledspecificallyforthispurpose No yes Equipmentisjustbeinginstalledspecificallyforthispurpose No yes Equipmentisjustbeinginstalledspecificallyforthispurpose No yes Equipmentisjustbeinginstalledspecificallyforthispurpose No yes Equipmentisjustbeinginstalledspecificallyforthispurpose No 'Org'hasequipmentthatcanbeutilizedtodesignmostanytestfordestructiveandnon destructiveevaluation. Notintegrated.Individualtestequipment. Yes Yes Equipmentisjustbeinginstalledspecificallyforthispurpose No Yes Equipmentisjustbeinginstalledspecificallyforthispurpose Yes +/10kVat250kW Yes Equipmentisjustbeinginstalledspecificallyforthispurpose No Yes Equipmentisjustbeinginstalledspecificallyforthispurpose No Yes Equipmentisjustbeinginstalledspecificallyforthispurpose yes wearegettingsimulator/sbytheendofthismonth Yes Yes yes Yes yes wearegettingsimulator/sbytheendofthismonth Yes No No SCE Confidential Page 9

114 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent05 Respondent06 Yes No Comments Yes No Comments Yes No Comments Respondent07 No yes No Wecansetupanyradionetworkconfigurationrequiredperclientrequirements.Wedothis frequentlyforcybersecurityanalysisofhanandotherfieldequipmentcommunications mechanisms. no Yes no Yes no Yes no Yes no Yes no No 'Org's'facilitiesarenotdedicatedtooneparticularproblem,butaremoregeneralizedsothat theycanbecustomizedtoaclientsparticularneeds.givenaclientrequirementanyofthe belowcouldbeconfigured. Yes ControlsinHILandpowerelectronicsmodeledinRTDS yes Equipmentisjustbeinginstalledspecificallyforthispurpose Yes YesforEVandstoragebutindividualpieces.Notintegrated Yes InthepasthaveinterfacedonsiteEVchargerswithutilityDR yes No yes Potentiallyitcanbasedonguidancefrom'outsideorg'. No no 'Org'hasadataanalyticsgroupthathasexperienceinmultipledomains.Givenclient Multiplesoftwaretoolsareavailable:ETAP,PowerFactory,OpenDSS,GidLabDaswellasABB Yes yes requirementstheycouldapplytheirexperiencetothedistributiongriddomain. DMS No yes Yes yes theextentofwhichdependsonthespecificusecase. No Yes yes wehavebuiltnumerousmodelsandanalyzedtimeseriesdataforexampleforoutage managementusingdisturbancerecords No Yes yes withtworealtimesimulators:rtdsandopalrt Yes yes Yes yes 'Org'hasexperiencewithModbusandIEC61850andcandesignatestplatformifaclient desiredonefortesting. Yes yes No yes Yes yes No yes Wecansimulatealmostunlimited61850devices.WecansimulatealmostunlmitedDNP3 devices. 51 SCE Confidential Page 10

115 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent05 Respondent06 Yes No Comments Yes No Comments Yes No Comments Respondent07 x Ourtestdistributioncircuitislimitedto12.65kV. Itisanisolatedcircuitthatcanbeislandedfromthegridfeedasneeded. Potentiallyitcanbasedonguidancefrom'outsideorganization.' Potentiallyitcanbasedonguidancefrom'outsideorganization.' 'Org'isintheprocessofdesigningandbuildingatestmicrogridcapableofoperatingat distributiongridvoltages. Thefacilityonlyhasoverheadconductors.Undergroundcouldbelayedinconduitonthe groundbuttheroughrockyterrainprohibitsburyingcable. ThefacilitycouldbemodifiedtoprovideHiZfaulttestingwithguidanceonhowtodothat safelyforoverheadconductor. Potentiallyitcanbasedonguidancefrom'outsideorganization.' Potentiallyitcanbasedonguidancefrom'outsideorganization.' Potentiallyitcanbasedonguidancefrom'outsideorganization.' Inasinglephasesetupitcanconfiguredin1mileincrementsuptothreemiles. No 2channelsarepotentiallyavailabledependingonthesizeofthebatterysystem.Testsofthis natureareusuallyconstructedspecificallyforclientneeds. No 3channelsareavailableforbatterypacksupto125kW. No 120channelsareavailableforindividualbatterycelltesting.Wecurrentlyrunanindustry consortium(energystoragesystemevaluationandsafetyessesii)fortestingofindividual lithiumionbatterycells.alltestingisdoneatourfacilities. No Yes OnlythecontrolsinHILconfiguration Yes Yes Wehavenotyethadaclientrequirementforthis,butwedohaveourownsubstationonsite andcouldpotentiallyworkwithourlocalutilitytoconnectanesstothegrid. No No WedonothaveadedicatedESStestingfacilitybutcandesignatestenvironmentgivenclient requirements. x 52 No SCE Confidential Page 11

116 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent05 Respondent06 Yes No Comments Yes No Comments Yes No Comments Respondent07 Org'hasbeentestingfueleconomyandemissionsofvehiclesforover40yearsandhas completetestingservicesforallfederalstandards. No 'Org'hasbeentestingfueleconomyandemissionsofvehiclesforover40yearsandhas No completetestingservicesforallfederalstandards. 'Org'hasbeentestingfueleconomyandemissionsofvehiclesforover40yearsandhas No completetestingservicesforallfederalstandards. 'Org'doesnotmaintainEVSEequipmentspecificallyfortestingbuthasspace,electrical infrastructure,anddataacquisitionequipmenttodesignmostanytestforevse. wehavesuchfacilitiesin'location,'butnotinthe'location' No yes No yes No yes No no No yes Todatewehavehadnoclientrequirementstobuildthiscapabilitybutwehavetheability No yes andinfrastructuretodoso. Todatewehavehadnoclientrequirementstobuildthiscapabilitybutwehavetheability No no andinfrastructuretodoso. No yes yes Yes ThroughRTDS Org'candesignmostanytestrelatedtoelectricvehiclesandtheirinteractionwiththegrid. No 'Org'hasalonghistoryofresearch,development,andtestingofpowersystemsofmany No wehavesomefacilitiesin'location' types. Upto30kW,480Vac(3ph),suppliedbyprogrammablepowersupply,feedingloadbanks. yes Measurementswithdifferentialvoltageprobes,currentprobes,andpoweranalyzers. 4160Vac(3ph)testsetupwillbereadysoon Upto1000Vdc(highervoltagesmaybepossibleatreducedpowers),suppliedby yes programmablepowersupply,feedingloadbanks.measurementswithdifferentialvoltage probes,currentprobes,andpoweranalyzers.6kvdctestsetupisbeingplanned. Potentiallyitcanbasedonguidancefrom'outsideorganization.' Potentiallyitcanbasedonguidancefrom'outsideorganization.' 'Org'hasamixtureoflightandheavydutydynamometersfortestingofemissionsstandards No forstate,federal,andmanycountries. 53 SCE Confidential Page 12

117 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent08 Respondent09 Respondent10 Yes No Comments Yes No Comments Yes No Comments Organization'currentlyhasasmartgridlabandproductionfacilityinWendell,NCthat designs,configuresandtestsrealtime,highspeeddistributionautomationsystemsforda applicationsinvolvingnetworkreliability(e.g.,ats,flisr),networkefficiency(e.g.,cvr)and otheradvancedapplicationsinvolvingdgintegration(e.g.,dgdtt,dgislandingand microgridprotection). Organization'usesOmicrontestssetsforsecondaryvoltageandcurrentinjection.For advancedtesting,'organization'doesownfacilitieswithrtdstestequipmentingermany. We buy or rent equipment as needed, and operate it internally. UsingtheOmicronRelaySimTestsoftware,'Organization'hasperformedDistributed synchronouscoordinationfieldtestingofaninserviceautomateddistributionfeedersystem. RelaySimTestallowsrealtime,dynamictestingoffeedersbothinthelabandinthefield. 'Organization'planstoexpandthiscapabilityinthefuture. Organization'hasanajoiningsubstationautomationlabatthesameWendellfacilityforIEC 61850testing.'Organization'hasacybersecuritybusinessunitin'location.'Also 'Organization'hasadedicatedComputerEmergencyResponseTeam(CERT)thatassistwith producttestingintheareaofcybersecurity. TheDistributionAutomationlabin'location'hasfacilitiestosimulatedistributionfeeders usingtwosubstationcircuitbreakersandupto20switchesandreclosers.thelabowns3to5 Some IEC substation automation lab testing is performed for automation projects OmicrontestsetsforinjectionandplantopurchasemoretestsetsandtheOmicron we undertake. RelaySimTestsoftware. WehaveafullscaleRTDSandGooseandsamplevaluemessagingtestsetup x The'name'labdoesnothaveanRTDS,but'organization'hasaccesstoanRTDSfacilityin 'location'andthertdstestfacilityat'organization'in'location.' x Our facility currently has the infrastructure to fully test next generation broadband wireless systems through the use of various network test tools such as JPERF/IPERF, Smatbits, and SiemenshastheabilitytotestWiMA,WiFI,alltypesofcellularsystems,including3Gand ASCE test sets (DNP3). We are also equipped to fully test the end-to-end capabilities of nextgen communication systems that leverage a multitude of Industrial Internet of Things 4G,aswellasotherRFtechnologies. communciaiton systems (including cellular), Lower Power Area Networks (Zigbee and Low Weareacertificationandvalidationlabaccreditedinternationally Energy Bluetooth). Yes,wehaveperformedintegrationandtestingofsomeresidentialsolaPVinvertersaspart ofutilityprojects. Rooftopsolararrayavailableforinvertertesting We don not have test facilities specifically aimed at these technologies No. Wehavecapabilitiestoexpandtotheseservices No. Wehavecapabilitiestoexpandtotheseservices No. Wehavecapabilitiestoperformthesetests Thereexistsalabin'location'withtheabilitytoconnectlowvoltagecomponentsandto x operatethemisolatedfromthemaingridasanisland. ThelabinGermanyoffersthepossibilitytoimposecertainvoltagesandfrequencytransients bymeansofinverters. x We use our own inverters to mimic sources and loads. Thelabin'location'offersthefeaturesbelow: x x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. Thelabin'location'offersthefeaturesbelow: ProgrammableDCPowerSupplies x We buy or rent equipment as needed, and operate it internally. PVproductioncanonlybemodelledbyprogrammableDCsources x We buy or rent equipment as needed, and operate it internally. Viaprogrammableinverters x We buy or rent equipment as needed, and operate it internally. Viaprogrammableinverters x We buy or rent equipment as needed, and operate it internally. Viaprogrammableinverters x We buy or rent equipment as needed, and operate it internally. Possible,butnooutoftheboxsolutionavailable x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. x We buy or rent equipment as needed, and operate it internally. 54 SCE Confidential Page 13

118 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent08 Respondent09 Respondent10 Yes No Comments Yes No Comments Yes No Comments ForDistributionAutomationapplicationsonly. x x HAN: Sniffers, Zigbee dongles. RF: antenna, spectrum analyzer, test harness for interference, remote sensors for coverage / RSSI testing. FAN:Network, Mesh, Pt to Pt. Throughput and CertifiedlabsforZigbee,JupiterMesh,WiSunandWiMax interference testing. with and without shielded (Ramsey) enclosures, NTP time and reciever sensitivity (stepped attenuators) to exercise mesh route re-building, all with controlled load traffic generators. x x x x We make, buy, or rent equipment as needed, and operate it internally. x We make, buy, or rent equipment as needed, and operate it internally. x Thelabin'location'offersthefeaturesbelow: x EnergySorageandRoofTopPVexisting,otherstobemodelledbyexistingprogrammable inverters x InternalNetworkInterfacecurrentlyIEC butextensiontoDNP3possible.Dueto securityrestrictionsnoexternalnetworkinterface x Microgridcontrolworksinclosedloopwiththeavailableassets x Usecaseshavetobemodelledonebyone x Organization'facilityin'locations'hassimulatorsadnasupercomputerforuseinasoftware labenvironment.nohardwaretestingtakesplaceatthesefacilities. 'Organization'providessoftware(PSS E,PSS Sincal,PSS ODMS,PSS MOD,PSS MUST, SIGUARDPSA,SIGUARDDSA),T&Dpowersystemmodelingandstudyusingcustomer x preferredsimulationtool(pslf,pscad,cymedist,synergi,etc).'organization'alsoprovides communicationconsultingservices,'organization'developedauniquesmartgrid communicationssimulator,called'name',whichhastheabilitytoevaluateandrankvarious communicationstechnologies(suchaslte,wima,wifi,wirelessmeshandmore) accordingtocoverage,costandperformancewhenusedinvarioussmartgridapplications. AcombinationofAMIMeterdata,GISassetmodelsanddatafromDAandSAdatasources willbeusedtoproducebothdynamicandsteadystatesimulationsofthenetwork.this x We have capability but normally do not work with AMI data. dynamicloadflowsolutionwillbebuiltontheenergyipplatformandleveragesbigdata technologiessuchashadooptoingestandprocessavastamountofdata. Organization'hassoftwaresimulatorsandasupercomputerforfastmodeling.Howeverwe candotwooptions: Option1)'name',realtimesimulatorofprotectionrelaysandexcitationsystemsfodifferent distributedgenerationtechnologies.ifneededtheunitscanbelocallydeployedtocustomer x facilityforfastersimulation,testinganddiagnostics. Option2)PartneringwithRPICenterforFutureEnergySystems(CFES)tosimulatethe integrationofderandtesttheminanrtdslabnear'location'. Yes,wecansimulateadistributionsystemindifferentsoftware,i.e.usingCymDistand x PSS SINCALandbenchmarksolutionsandsimulationvisualization. Siemenstorespondatafurtherdate.Thisrequiresfurtheranalysis. x TheDEROptimizerproduct,thatiscurrentlyintheworksaddressestheutility sneedto accuratelyunderstandthedercapacityonanodelevel.inadditiontoprovidingavailable capacityresults,itwillalsopointoutkeyproblemsthatcanstematdifferentnodesbasedon x differentadoptionratesofder.examplesofimpactthatwillbestudiedandreportedon includereversepowerflow,voltageregulation,shortcircuitcontributionratioandsoon. SmallscaletestingonlyusingOmicrontestsetsandOmicronRelaySimTestsoftware. x Controlintheloopcanbeperformedexcludingpowerintheloop AllofourUSlabshavesoftwareandhardwaresimulators.NoneoftheUSlabshavelive substationenvironmentfordevelopmentandtesting. x SmallscaletestingonlyusingOmicrontestsetsandOmicronRelaySimTestsoftware. x x x The'location'labdoesnothaveanRTDS,but'organization'hasaccesstoanRTDSfacilityin 'location'andthertdstestfacilityat'externalorgname'in'location. x Thisdependsonthetestingrequired.Thismaybepossibleusingsubstationsimulators OmicrontestsetsandOmicronRelaySimTestsoftware. 55 x We do not have 70 racks - a more limited number. SCE Confidential Page 14

119 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent08 Respondent09 Respondent10 Yes No Comments Yes No Comments Yes No Comments In'location'wedesign,test,andmanufactureGasCircuitBreakers(15kVto550kV),Large DistributionTransformers(12kVto69kV),andVoltageRegulators(2.4kVto35kV).Impulseand dielectrictestingfacilitiesareavailable. Ataspeciallabin'location','organization'globalresearchunitCorporateTechnology(CT)istesting howsmartgridswillworkinthefuture.researchersinthe170squaremeterlabcansimulate almostanysmartgridbecausethefacilityisequippedwithcontrolcabinetsfullofbatteriesaswell Organization' has two high power test facilities. One is a generator feed power laboraroty with aswithacogenerationplant,anemergencypowerunit,anadjustablelocalgridtransformer, 1700 MVA short circuit capacity and test voltages from 12 to 38 kv. Currents can be adjusted variousloadsandconverters,tworefrigerationunits,andawaterpurificationplant. from 10's A of load current up to 2000 A of load current, and fault currents from 100's A up to x 63 ka. The second facility is a continuous power facility coupled to 25 kv feeder with ability Thecircuitbreakerheadquartersin'location'hastheabilitytotestforavarietyoffault/short to source and sink power up to 2 MVA. The aswers below are mixed between the two circuit,dielectric,power,andmechanicaltestduties.upto63kafaulttestingat500kvispossible. facilities. 'weblink' Theproductionareasmanufactureequipmentthatisdeliveredtohundredsofutilityandindustrial x customersaround'location'. sourcesubstationisownedby'utilityorgname'andfeedstheentire'geographiclocation'area x 'organization'facilityin'location'supportsthis. x x x 'organization'facilityin'location'supportsthis. x 'organization'facilityin'location'supportsthis.b48:r/rationlike12kvbutlv x x x x 'organization'facilityin'location'supportsthis.laberls,b31 x x x x Thecircuitbreakerheadquartersin'location'hastheabilitytotestforavarietyoffault/short circuit,dielectric,power,andmechanicaltestduties.upto63kafaulttestingat500kvispossible. x x x x x x x Location'PolygenerationLab x Yes,forDAapplications x x We make, buy, partner, or rent equipment as needed, and operate it either internally or at other facilities. Varies - not setup to specifically test batteries continuously. x Wemake,buy,partner,orrentequipmentasneeded,andoperateiteitherinternallyorat otherfacilities. Varies - not setup to specifically test batteries continuously. x Wemake,buy,partner,orrentequipmentasneeded,andoperateiteitherinternallyorat otherfacilities. Our focus is on complete battery banks, not cells. x x 56 x x x x x Two or more but not simultaneously power output. x SCE Confidential Page 15

120 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent08 Respondent09 Respondent10 Yes No Comments Yes No Comments Yes No Comments x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x x 57 SCE Confidential Page 16

121 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent11 Respondent12 Yes No Comments Yes No Comments Yes No Comments Respondent13 Yes WehaveonegridsimlulatorandRTDSinadditiontotherealdistributionfeederhardware withthefeederengine. Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation Yes Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation Yes Organization'hasaccesstomultipleRTDSracksandcardswithmultiplerelaysandother Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation equipmentforpowerhardwareintheloopsimulation.wealsohaveanopalrtunitfor simulatingpowerelectronicsintheloopinconcertwithrtdssimulators.ourfacilitiesat Yes 'locations'canbeconfiguredforremoteaccessaswell.wecompletedaresearchprojectfor 'externalorganization'usingthesesamesystems. Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation Yes Bothclosedandopenloophardwareaswellsoftwareinthelooptestingcanbeperformed withtheuseofappropriatelabhardwareandsoftware communicationlabhas multipleamplifierswithprimarysimulationandsecondarysimulationwhicharephyically separatedbutcanbedigitallycombined PrimaryandSecondaytestsetshavedifferentdriversforcurrentandvoltagesbuttheyare integratedinthefacilitynetwork. Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation Ourfacilityhasmultiplelabsthat sareconnectedtotheutilitynetwork.thereissecurityand segregationinplacetoensuresafetywhileotherdevelopmentis Yes Wehavethefacilitywhichcompriseofmultiplelabscumulativelyabletoperformallthe testingrequired Several'Organization'AutomationproductssupportIEC61850asastandardprotocol. InourDistributiontestyardwecouldcreateanysimulatedenvironmentwiththehelpofthe Yes Asnotedabove,ourlabshavemultipleRTDSunitswithmoretobepurchasedinthecoming Thisquestionisambiguous.Theanswerisyeswithcaveatsaboutnextgeneration. hardwareandsoftwarefornextgenerations/sanddatesting. monthsthroughagrantfromthedepartmentofdefense.the'externalorganization'at 'location'alsousesopnetcommunicationswhichcanemulatewirelesscommuncations. facilityisequipedwiththertdsandbeingusedforthesecondarysystemsimulationatthis Yes Yes.The'Organization''locations'isequippedwithRealTimeDigitalSimulators time.wehavenotsofarusedthertdsfortheprimarysystemtestingyet.thesystemcould beaccessedthroughthenetwork. thefacilityhastheindependentnetworkinfrastructuretotestnumerousnetworkintegration solutions Organization''sWirelesstestingcapabilitiesaresignificantas'Organization'isaproviderof WirelessNetworkCommunications. At'location',our'locationname'labiscurrentlyworkingonconformancetestdevelopfor IEEE1547usinganABBinverterandour40kWrooftoparray.Wecanalsoemulateavariety ofloadsanddrivesthroughotherdevices.wedonothaveaccesstocontrollablerootopac unitsnortoductlessresidentialunits. Yes Yes 'Location'usesaprogrammableACpowersupplyforthesesituations. WehaveverysophisticatedtestsetupbuiltfortestingtheSmartInverterswiththeRTDSand Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. GridSimulators Wehavealabdedicatedforcommercialandresidentialunitstesting Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Wehavealabdedicatedforcommercialandresidentialunitstesting Weareplanningtoextendoutexistingtestingcapabilitytobeabletosecondaryvoltage Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. regulationdevicesinnearfuture. yes,wearefullycapableofcreatinganisolatedcontrolledenvironmentfortestingutilityand Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. customerdevices. wehavetheabilitytocreatevoltageaswellasfrequencytransients(onlyatsecondary voltagedevices) Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Wecanusepoweramplifiersandgridsimulatorforgenerationofthedesiredtesting scenraios Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnotcurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnotcurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnotcurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnotcurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. WeareusinggridandPVsimulatorsvoltagevariablecapbilitywiththeinternalsoftwarefor assesingthepvinvertersvoltageandfrquencyprotection. WeareusinggridandPVsimulatorscapabilitieswiththecustomsoftwareforassesingthePV invertersridethrucapabilties Agridsimulatorisusedtogeneratevoltageharmonicsandhighresolutionmonitoring equipmenttoassessdeviceperformance. Wecancreaterealfaultsorshortcircuitsviaphasetophaseandphasetogroundsimulations inanisolatedenvironment. Wecancreaterealfaultsorshortcircuitsviaphasetophaseandphasetogroundsimulations inanisolatedenvironment. Yes Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Fullyintegratedinthesmartinvertertestsetupatthesecondaryvoltagelevel Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Fullyintegratedinthesmartinvertertestsetupatthesecondaryvoltagelevel Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Locations'havethesecapabilitiesthroughourPowerHardwareintheLoopsystemsandcan Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Fullyintegratedinthesmartinvertertestsetupatthesecondaryvoltagelevel linkmultipledevicestogetherwithcontrollersintheloopaswell. Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Partofprimarytestingfacilitywiththehelpofpoweramplifiers. Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Integralpartofthefacility Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Integralpartofthefacility Partofprimarytestingfacilitywiththehelpofpoweramplifiers. Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting PartofHighCurrentyeartestingfacilitywithabilitytogenerateactualfaults. Yes The'Organization'facilityin'location'doesnotcurrentlysupportsuchtesting PartofHighCurrentyeartestingfacilitywithabilitytogenerateactualfaults. 58 SCE Confidential Page 17

122 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent11 Respondent12 Yes No Comments Yes No Comments Yes No Comments Respondent13 WehaveadedicatedlabfortheGridEdgerelatedtestingthatisfullysecureandprovides holitistictestingplatformforgridedgesolutions WehaveadedicatedlabfortheGridEdgerelatedtestingthatisfullysecureandprovides holitistictestingplatformforgridedgesolutions WehaveadedicatedlabfortheGridEdgerelatedtestingthatisfullysecureandprovides holitistictestingplatformforgridedgesolutions ThisareaoftestingisnotourspecialtybutwedohaveaccesstoaFaradaycageat'location'. Weusevariouscommunicationmethodsinourresearchandarefamiliarwithmultiple communicationmethods.wearealsopartnerswiththe'externalorganization'whichdoes havecapaibilitiesintheseareas. Organization''sWirelesstestingcapabilitiesaresignificantas'Organization'isaproviderof WirelessNetworkCommunications. Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. yes,twosignalgeneratorsandanalysers Weareworkingononeprojectwhichisprimarilityfocussedonthat Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Multipletestharnesses Organization''sWirelesstestingcapabilitiesaresignificantas'Organization'isaproviderof distributedamongmultiplelabsandvariouswaystocreateit PowerLineCarrierNetworkCommunications. Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Ourfacilityhasadedicatedlabfullyequippedwiththeisolationboxandfaradaycage integratedtoournetworktestenvironment. OurAdvancedtechnologytestinglabisbuilttotestcustomerapplicationsandappliances Yes Organization'hasafacilityin'location'forsuchtesting Organization'hasaCenterofExcellencein'location'dedicatedtoElectricVehicles,Charging Yes Boththe'locations'labshavethecapabilitytoperformlowandmediumvoltagetestingand StationsandGridIntegration.Thatfacilitydoesnotincludeenergystorage. evaluationofchargingstations,batterystorage,etc.bothlabscanalsooperateingrid connectedorgridisolatedmodes. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. oneofthemostdevelopedphysicaltestseupwithenergystorageandoldestevtestsetup. integratedtoutilitynetworkcapableofcreatingafullydevelopedcontrolledenviroment Withthehighprecisiondatamonitoringwecanhavethecapabilitytocreateanysandbox environment Alltheusedcasesdesiredbytheutilityorthecustomercouldbecreated Weareusingthecompanytoolsontopofthespecialtools(includingopensource)avaiablein themarket. Yes Organization''sCYMEEngineeringAnalysisproductsarewidelyusedby'Organization' EngineeringresourcesandUtilitycustomersfordistributioncircuitmodeling. Wearecurrentlycreatingdetailedbeyondthemeterloadmodelsforresidentialcustomers Yes andloadprofilesforcommercialcustomers.wearealsoworkingonutilizingsmartmeter databeyondthecashtometer. OurfacultyandstudentsarefamiliarwithmultiplesimulationcodesincludingCYME, OpenDSS,andourownLargeScaleSystemSimulationTestbedforevaluatingthe'orgname' Systemdesign.WehavealsousedmultiplevisualizationtoolsfordataanlysisincludingSAS, Matlab,etc.Wehavealsoperformedhostingstudiesforotherelectricutilities. Wearealsoworkingoncreatingabetterplateformforanalyzeandvisualizedatafromtests Yes andbulkdatafromthegrid. Organization''sCYMEEngineeringAnalysisproductsarewidelyusedby'Organization' EngineeringresourcesandUtilitycustomersfordistributioncircuitmodeling. Wecanevaluatemanysoftwaretoolsinasecuredtestenvironmentwithoutaffectingthe Yes grid. Wehavetheabilitytotestanddevelopnewdatabasestructuresandweareworkingon Yes developingdigitalutilityforthefuture. Yes Wehavetheabilitytoperformtimeseriesanalysis. Organization''sCYMEEngineeringAnalysisproductsarewidelyusedby'Organization' EngineeringresourcesandUtilitycustomersfordistributioncircuitmodeling. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. OurdedicatedDistributionTestYard(DTY)isoneoftheuniquefacilityinNorthamerica wherethiscanbedone DTYwasdevelopedtobeabletoevalautesmartgridtechnolgiesinanelectricrealgrid. Yes Organization'hassufficientLVandMVtestingfacilitiesin'locations'forsuchtesting. Yes Organization''sSubstationAutomationSMPGatewayDataConcentratorsupportsover80 deviceprotocols. Yes Yes Organization'hasfacilitiesin'locations'thatsupportrealtimesimulation Organization''sSubstationAutomationQualityAssuranceinfrastructuresupportsimulationof Yes largesubstations 59 SCE Confidential Page 18

123 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent11 Respondent12 Yes No Comments Yes No Comments Yes No Comments Respondent13 OurdedicatedDistributionTestYard(DTY)isoneoftheuniquefacilityinNorthamerica wherethiscanbedoneincombinationwiththehighcurrentyard. Organization''locations'facilityincludesHVinfrastructureforsuchtesting. Organization''s'location'facilityhasadedicatedHVyardwithasinglecircuit. Organization''s'location'facilityhasadedicatedHVyardwithasinglecircuit. Adedicatedsubisconnectedtothefacility thefacilityhasbeenusedforfan,vvoandflisrtestinginthepast multipledevicesincludingbreakers,switches,reclosers,capacitors,voltageregulatorsare partofthefacility HCYcancreateupto80kAfaultcurrent thefaciltieshasotherlabsthathasthegridsimulatorwhichisdigitallyconntected multipledevicesincludingbreakers,switches,reclosers,capacitors,voltageregulatorsare Organization''s'location'facilityhasthecapabilitytosupportallnameddevicesbutdoesnot partofthefacility currentlyincludebatterystorage,smartinverters,oragridsimulator Bothoverheadandundergroundinfrastructurewithbreakers,switches,reclosers,capacitors, voltageregulatorsispartofthefacility Facilitycouldbeconfiguredtocreateanyphysicalscenriointhecontrolledenvironment. Organization''s'location'facilitydoesnotcurrentlyincludebatterystorage. Organization''s'location'facilitydoesnotcurrentlyincludeintegratedgridsimulatordevices. Organization''s'location'facilitydoesnotcurrentlyincludeintegratedgridsimulatordevices. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe configuredtodosoasneeded. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe configuredtodosoasneeded. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe configuredtodosoasneeded. The'Organization'facilityin'location'supportsaradialfeederonly. Wehavedoingtheperformancetestingandpioneeringtheenergystoragefortheutility manyyears.wehavebeeninvolvedinperformingmultiyearlabandfieldtestingofboth smallscaleandutilitysizeenergystorage.priorlabtestinghasbeenlimitedtotemperature No controlbetween10cand50choweverwehaveindustrialcoolingandheatingsystemsthat maybecapableofdrivingconditionsbeyondthisrange. Threeindedicatedenvironmentallycontrolledchambers,moreifenvironmentalcontrolisnot Largebatterysystemscannotcurrentlybetestedinthe'Organization''location'facility. required. Priortestinghasbeenlimitedtotemperaturesbetween10Cand50Choweverwehave Wedonothaveaccesstoenvironmentalchamberstouseintesting.WedohaveanArbin No industrialcoolingandheatingsystemsthatmaybecapableofdrivingconditionsbeyondthis batterytestsystemforcelltesting.wecantesta250kwbessbutnotinanenvironmental range. chamber. Threeindedicatedenvironmentallycontrolledchambers,moreifenvironmentalcontrolisnot Largebatterysystemscannotcurrentlybetestedinthe'Organization''location'facility. required. Wehavethecapabilitytodocellleveltestingalthoughinitialtestinghasbeenprimarily No focusedonmodulesandesspackages. Threeindedicatedenvironmentallycontrolledchambers,moreifenvironmentalcontrolisnot Largebatterysystemscannotcurrentlybetestedinthe'Organization''location'facility. required. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. Yes The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Yes configuredtodosoasneeded. Weregularlydevelopproprietarypowerconversionsystemsandcreatetestrigsfor evaluationofthosesystems.throughourphilcapabilities,wecanalsoevaluategridimpacts andbessperformanceinresponsetogridanomalies. Yes WehavetestedthisinthepastaspartofPIERprojectsandareslatedtotestadditional completeessthroughepicprojects WehavetestedvariousPCSanddrivepackagesalready. WehavetestednumerousBMSbothcoupledwithbatteriesandindependently. WehavetestedmostcommoncontrolandcommunicationinterfacesincludeCAN,Modbus TCP/IP,ModbusRTU,DNP3.0,andvariousserialcommunications. Wehaveconductedvariouspowerqualitytestsandhighspeedtransientperformance characterizationbothinthelabandfield. Wehavedonethiswithnumerousprojects. Yes Capabilitybutthisspecifictestingisnotdone Threeindedicatedenvironmentallycontrolledchambers,moreifenvironmentalcontrolisnot required. The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe PVinverters,Butdonotdopaneltestingatthistime Yes configuredtodosoasneeded. 60 SCE Confidential Page 19

124 SCE T and D Benchmarking Advanced Technology Laboratory Capabilities Survey May 2016 Respondent11 Respondent12 Yes No Comments Yes No Comments Yes No Comments Respondent13 No Weusedoutsidefaciltiesforgettignthisworkdone No The'orgname'at'location'isanaffiliatedlabwithFREEDMandusesafullchassis Yes dynamometerforfueleconomyevaluationsforlightdutyvehiclesofallhybridandfullelectric configurations.wedonothaveaheavydutydynonordoweperformemissionstesting. No No No Weusedthirdparyservicesforthesetests Weusedthirdparyservicesforthesetests No MGTFandATPLhavetheabilitytoperformvarioustestingscenriosforEVevaluation Yes Wecantestat110V,208Vand240Vwithpowerratingsof19.2KW. Yes Wearebuildingtheinfrastructurenecessaryforthelevel3testing Yes Wearebuildingtheinfrastructurenecessary Ourlabsat'locations'arearefullyconfigurabletoevaluatemultiplechargingstandardsand Wehavetheabilitytoexportpowertothegridwiththehelpofnecessaryrelaysetc. multiplevoltagesandloads.wehavealsodevelopedintellectualpropertyforwirelesspower Yes transferanddcfastcharging. Yes wehavetheabilitybutnotsureabouttheneedforthesame Yes Yes Wehavedonesomeworkinthepastaroundinductivecharging Yes extensivetestingbothinthelabaswellasfield Yes Facilityiscapableoftestingtheintegratedgridbuthasnotbeenexploredjustyet. MGTFandATPLhavetheabilitytoperformvarioustestingscenriosforEVevaluation Yes Wearecapableofconfiguringourtestfacilityforallthestandardsevolvingorestablished Yes Wearecapableofconfiguringourtestfacilityforallthestandardsevolvingorestablished Yes SmartInvertertestsetupcouldbefurthermodifiedforVtoGtesting MGTFandATPLhavetheabilitytoperformvarioustestingscenriosforauxiliarypower system Yes The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Weareplanningtoaddthiscapabilitytoourfacility Yes configuredtodosoasneeded. Yes The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe configuredtodosoasneeded. Wehavethecapabilitywhichiscurrentlybeingutilisedinbothenergystorageandsmart invertertesting Wehavethecapabilitytodothistestingatvariouspowerlevels Yes Yes Yes Wehavethecapabilitytodothistestingatvariouspowerlevels Wehavethecapabilitytodothisperourcodesandstadardswiththehelpofotherlabs Yes The'Organization'facilityin'location'doesnocurrentlysupportsuchtestingbutcouldbe Extensivetestingwasdoneformanyrenownedindustryvendorsforhelpingthemdevelopa Yes configuredtodosoasneeded. product Yes therearefacilitieswithinourutilitywiththecapability Yes No No Yes No 61 SCE Confidential Page 20

125 62 Workpaper Southern California Edison / 2018 GRC Pleaseanswerthefollowingquestionsthatareinreferencetoyourcurrentfacilitiestechnicaltestabilities.Thesequestionsareprefaced withthefollowingstipulationsinorderfora"yes"tobeavalidresponse: 1.Thetestfacilitydoesnotneedtoundergosignificantremodelingtoaccommodatetestingofsuchtechnologyoriftestfacilitycanmeettestcapability,butrequiresminorretooloffacilityortestapparatustoaccommodatetestingofsuchtechnology,theretooltimewilltakelessthan1weekto complete. 2.Testfacilitycurrentlyhasallnecessaryequipmenttoconducttestingwithouthavingtoprocuretestequipmentbyeitherpurchasingorrent/leaseagreementstomeettestingcapabilities. 3.Testfacilityhasqualifiedpersonnelonstafftoconductsaidtests. 4.DatathatresultsfromalltestsmustbecollectedfromcalibratedNISTtraceableequipment(whereapplicable)andmustbeassessedusingstandardandacceptedpracticesofuncertaintyanalysis. SurveyQuestions Yes No Comment EnergyStorage(BatteryProfiling,Testing,andEvaluationCapabilities) 40 Does your facility have the capability to test large batteries systems with maximum ratings of 900 V DC, 1000 A DC, and 250 kw in large temperature controlled environments (up to 870 cubic ft, between -45 C and 70 C)? 41 What is the total number of individual tests on large batteries systems that can be tested at any given time? Note: this question refers to the number of individual tests that can be run in parallel. 42 Does your facility have the capability to test batteries packs with maximum ratings of 445 V DC, 265 A DC, and 125 kw in large temperature controlled environments (up to 64 cubic ft, between -45 C and 70 C)? Y Wecantest6batterysystemsatanygiventime. N Ourfacilityhastestedbatterypacksonlyupto300VDCatmaximumof150Ainroomtemperatureenvironments. 43 What is the total number of individual tests on batteries packs that can be tested at any given time? Wecantest8batterypacks,or14batterypacksifnottestingbatterysystemsatanygiventime. 44 Does your facility have the capability to test battery cells with maximum voltage of 5 V DC and 400 A DC in temperature controlled environments (between -34 and 70 C)? 45 What is the total number of battery cells that can be tested at any given time? Note: this question refers to the number of individual tests that can be run in parallel. 46 Does your facility have the capability to test a complete energy storage system (ESS) with maximum ratings of 480 V AC, and 250 kw and up to 14 sq.ft. footprint per system? N Thesmallestcellsthatwecantestis12VDC. 2batterycellsat12VDCcanbetestedatanygiventime. Y Ourfacilitycantestsystemsat480VACupto500kWwithfootprintsof200sq.ft.

126 63 FenwickLabs:SurveySummary Background: TodeterminewhichentitiespossessSCE sneededcapabilitiesasurveywasconductedtargeting universities,nationallabsandenergyconsortia.sce,alongwith12entitiesrespondedtothesurvey, whichwasdividedintosevencategories:controls,distributionautomation,distributedenergy Resources,GridEdgeSolutions,DistributionGridAnalytics,PowerSystems,andSubstationAutomation. Controls:Thiscategoryiscomprisedofthefollowingfivequestions,oneofwhichcontainsasub question: Question1:Doesyourfacilitycurrentlyhavethecapabilitytorunrealtimesimulationofdistribution feeders? SCEalongwithtwelverespondents(1,2,3,4,6,7,8,9,10,11,12,and13)havethecapabilityto runrealtimesimulationofdistributionfeeders. Question2:Canyourfacilityperformhardwareandsoftwareintheloop(closedandopen)testing? SCEandallthirteenrespondentshavetheabilitytoperformhardwareandsoftwareintheloop testing. Question3:Isyourfacilitycurrentlycapableoftestingcontrolssystemsusingattenuatedradio communicationhardware? SCEalongwithninerespondents(3,5,7,8,9,10,11,12,and13)havethecapabilityoftesting controlssystemsusingattenuatedradiocommunicationhardware. Question4:Doesyourfacilitycurrentlyownandoperateamplifiertestsetsfordrivinghardwarewith secondaryvoltageandcurrentsignals?ifso,cantestsetsbedrivenbythesimulatorsinthefacility? SCEalongwithtwelverespondents(1,2,3,4,5,7,8,9,10,11,12,and13)currentlyownand operateamplifiertestsetsfordrivinghardwarewithsecondaryvoltageandcurrentsignals. o SCEalongwithrespondents1,2,3,4,7,8,9,10,11,12,and13possessthecapabilityto havetestsetsdrivenbythesimulatorsinthefacility.respondent5doesnotpossess thiscapability. Question5:Isyourfacilityintegratedwithsystemsinotherfacilities/labssuchascybersecurity, substationautomation,fieldautomation,fieldmessagebus,andenterprisebusarchitecture? SCE,alongwithelevenrespondents(1,2,3,4,7,8,9,10,11,12,and13)possessafacilityintegrated withsystemsinotherfacilities/labssuchascybersecurity,substationautomation,fieldautomation,field messagebus,andenterprisearchitecture. DistributionAutomation:Thiscategoryiscomprisedofthefollowingfourquestions: Question1:Whatareyourfacility siec61850testingcapabilitieswithregardtodistribution Automationsystems? SCE,alongwitheightrespondents(1,2,5,7,9,10,12,and13)havetheabilitytofullytestIEC 61850withregardtoDistributionAutomationsystems.Respondents8and11havesomeability totestthisaforementionedcapabilityaswell.

127 64 Workpaper Southern California Edison / 2018 GRC Question2:Isyourfacilitycurrentlycapableoftestingintegrationofnextgenerationsubstationand distributionautomationsystems? SCEalongwithelevenrespondents(1,2,3,4,6,7,8,9,10,11,and13)havethecapabilityof testingintegrationofnextgenerationsubstationdistributionautomationsystems. Question3:IsyourfacilitycurrentlyequippedwithRealTimeDigitalSimulators(RTDS)? SCEalongwithelevenrespondents(1,2,3,4,6,7,9,10,11,12,and13)haveafacilityequipped withrtds. Question4:Whatareyourfacility scurrentcapabilitiesforbroadbandwirelessnetworkintegrationof distributionautomationssystems? SCE,alongwithsevenrespondents(5,7,8,9,10,12,and13)havefullcapabilitiestotestnext generationbroadbandwirelessnetworkintegrationofdistributionautomationssystems. Respondent1hassomecharacteristicsoftestingnextgenerationbroadbandwirelessnetworks. DistributedEnergyResources:Thiscategoryiscomprisedofthefollowingfourquestions,threeofwhich aremultipartandonecontainsasubquestion: Question1:Whatareyourfacility scapabilitiesfortestingandevaluatingthefollowing:smart(solarpv) inverters,commercialrooftopa/cunits,ductlessresidentiala/cunitwithvariablefrequencydrives, and,secondaryvoltageregulationdevices? SCEhasfullcapabilitiesfortestingandevaluatingsmartinverters,commercialrooftopA/Cunits, ductlessresidentiala/cunitwithvariablefrequencydrives,andsecondaryvoltageregulation devices.respondent13has75%ofthesecapabilities,respondents6and9have50%,and respondents1,2,5,and8have25%ofthesetestingandevaluatingcapabilities. Question2:Doesyourfacilitycurrentlyhavetheabilitytoenergizeutilityandcustomerdevicesinorder tooperatetheminacontrolledenvironment,isolatedfromtheelectricgrid?ifso,doesyourfacility havethecapabilitytosubjectthesedevicestoabnormalvoltageand/orfrequencytransientsthatare representativeofactualeventsthatcanoccurontheelectricgridtounderstandthedeviceresponse duringsuchevents? SCE,alongwithtenrespondents(2,4,5,7,8,9,10,11,12,and13)havetheabilitytoenergy utilityandcustomerdevicesinordertooperatetheminacontrolledenvironment,isolatedfrom thegridandhavethecapabilitytosubjectthesedevicestoabnormalvoltageand/orfrequency transientsthatarerepresentativeofactualeventsthatcanoccurontheelectricgrid. Question3:Doesyourfacilityhavetheabilitytogeneratearbitraryandtransientwaveformswiththe programmablepowersupplieswhichallowtheassessmentof:pvinvertervoltage/frequencyprotection, ridethroughcharacteristics,antiislandingcapabilities,harmonicsgeneration,andfaultcurrent contribution? SCE,alongwithninerespondents(1,2,4,5,8,9,10,11,and13)havefullabilitytogenerate arbitraryandtransientwaveformswiththeprogrammablepowersupplies.respondents3and7 have80%oftheseabilities. Question4:Doesyourfacilitycurrentlyhavethefollowingequipmentandcapabilities?Ifyes,canthe facilitytestthefollowing:pvsimulators(programmabledcpowersupplies,programmableirradiance andtemperatureprofiles,gridsimulators(programmableacpowersupplies),voltageandfrequency transientgeneration,andarbitrarywaveformgeneration?

128 65 SCE,alongwiththreerespondents(4,9,and11)havefullcapabilitiestotestequipment. Respondent10has90%,respondents1,2,and13have81%,respondent8has64%,respondent 6has55%,andrespondent3has27%oftestingcapabilities. GridEdgeSolutions:Thiscategoryiscomprisedofthefollowing4questions,oneofwhichisamultipart question: Question1:Doesyourfacilitycurrentlyhavetheabilitytosupportsmartgridinitiativesthatrequire radiocommunicationstesting/evaluationand/orsmartmeterdataandinfrastructure? SCE,alongwithninerespondents(3,4,5,7,8,9,10,12and13)havetheabilitytosupport smartgridinitiativesthatrequireradiocommunicationstesting/evaluationand/orsmartmeter dataandinfrastructure.respondent2haspartialcapabilitiestotestsmartmeters,butnotradio communications. Question2:Isyourfacilitycurrentlycapableofusingsmartmeterdatatoimproveaccuracyofthe meter/transformercorrelationmodel? SCE,alongwithfiverespondents(3,5,9,12,and13)havethecapabilityofusingsmartmeter datatoimproveaccuracyofthemeter/transformercorrelationmodel. Question3:WhatareyourfacilitycapabilitiestotestradiocommunicationforHomeAreaNetwork (HAN)andFieldAreaNetwork(FAN)andothertelecomfordistributedfieldequipment? SCE,alongwithfiverespondents(5,9,10,12,and13)havethecapabilitytotestradio communicationforhanandfanandothertelecomdistributedfieldequipment. Question4:Isyourfacilityequippedwiththefollowing:signalgeneratorsandanalyzers,ZigBeesignal sensorsanddecoders,testharnesses,powerlinecarriersignalgenerator,radioisolationboxesand FaradayCage,andsmartmetersandcellrelays? SCE,alongwithfourrespondents(6,9,12,and13)arefullyequippedwithsignalgeneratorsand analyzers,zigbeesignalsensorsanddecoders,testharnesses,powerlinecarriersignal generator,radioisolationboxesandfaradaycage,andsmartmetersandcellrelays. Respondents3,5,and6have83%,respondent10has67%,respondent4has50%,and respondent2has17%oftheequipmenttestingcapabilities. DistributionGridAnalytics:Thiscategoryiscomprisedofthefollowingfivequestions,oneofwhichhas asubquestion: Question1:Doesyourfacilitycurrentlyhavetheabilitytoevaluateandutilizeseveralmodelingtoolsto developcircuitmodels?ifyes,canthesemodelsshowaccuratedynamicandsteadystatesimulations representingbeyondthemeterloadsleveragingsmartmeterdata? SCEalongwithtenrespondents(1,2,3,7,8,9,10,11,12,and13)havetheabilitytoevaluate andutilizeseveralmodelingtoolstodevelopcircuitsandshowaccuratedynamicandsteady statesimulationsrepresentingbeyondthemeterloadsleveragingsmartmeterdata. Respondents4and6havetheabilitytoevaluateandutilizeseveralmodelingtools,butdonot havetheabilitytoshowaccuratedynamicandsteadystatesimulations.

129 66 Workpaper Southern California Edison / 2018 GRC Question2:Doesyourfacilityhavetheabilitytoanalyzeandvisualizetestdataandresultstodevelop integrationstrategiesandinformfielddeploymentofcontrolequipment,energystorageandother devices? SCE,alongwithelevenrespondents(1,2,3,4,5,6,7,9,10,11,12,and13)havetheabilityto analyzeandvisualizetestdataandresultstodevelopintegrationstrategiesandinformfield deployment. Question3:Canyourfacilitycurrentlyevaluatedifferentsoftwareandsolutionsthatprovide visualizationofpowerdistributionsystems? SCE,alongwitheightrespondents(1,2,8,9,10,11,12,and13)havetheabilitytoevaluate differentsoftwaresolutionsthatprovidevisualizationofpowerdistributionsystems. Question4:Doesyourfacilitycurrentlyhavetheabilitytodevelop/evaluatenewdatabasestructures andmathematicalmethodologiessuchasdimensionreductiontohandledistributeddata? SCE,alongwithelevenrespondents(1,2,4,5,6,7,9,10,11,12,and13)havetheabilityto develop/evaluatenewdatabasestructuresandmathematicalmethodologies. Question5:Canyourfacilitycurrentlyconducttimeseriesanalysistodynamicallycalculatethe distributedenergyresource(der)hostingcapacityforanygivennodewithinthedistributionand transmissionsystemforanyhouroftheday? SCE,alongwitheightrespondents(2,4,8,9,10,11,12,and13)currentlyconducttimeseries analysistodynamicallycalculatethederhostingcapacityforanygivennodewithinthe distributionandtransmissionsystemforanyhouroftheday. PowerSystems:Thiscategoryiscomprisedofthefollowingthreequestions: Question1:Doesyourfacilitycurrentlyhavetheabilitytoconducthardwareintheloopcontrolsystem testing,protectiverelaytesting,wideareaprotectionandcontroltesting? SCE,alongwithtwelverespondents(1,2,3,4,6,7,8,9,10,11,12,and13)havetheabilityto conducthardwareintheloopcontrolsystemtesting,protectiverelaytesting,widearea protectionandcontroltesting. Question2:Doesyourfacilitycurrentlyhavetheabilitytoevaluatesmartgriddevelopmentforinclusion inanelectricalgrid? SCE,alongwithtwelverespondents(1,2,3,4,5,6,7,9,10,11,12,and13)havetheabilityto evaluatesmartgriddevelopmentforinclusioninanelectricalgrid. Question3:Doesyourfacilitycurrentlyhavetheabilitytorunlargescalerealtimesimulationsutilizing controlsystemandrelaycommunicationsequipment? SCE,alongwithtenrespondents(1,3,4,6,7,9,10,11,12,and13)havetheabilitytorunlarge scalerealtimesimulationsutilizingcontrolsystemandrelaycommunicationsequipment. Respondent2haslimitedabilitytorunlargescalerealtimesimulations. SubstationAutomation:Thiscategoryiscomprisedofthefollowingfourquestions:

130 67 Question1:Doesyourfacilitycurrentlyhaveaplatformtotestintegrationofinservicelegacy proprietarysubstationautomationsystemsbasedonmodbusplusandmodbusprotocolswithnewiec 61850openstandardssystems? SCE,alongwithtenrespondents(1,3,6,7,8,9,10,11,12,and13)haveaplatformtotest integrationofinservicelegacyproprietarysubstationautomationsystemswithnewiec61850 openstandardssystems. Question2:Doesyourfacilitycurrentlyhavedirectconnectivitytoatestenergymanagementsystemfor testingandintegratingnewsupervisorycontrolanddataacquisition(scada)systems? SCE,alongwitheightrespondents(1,2,7,8,9,10,11,and13)currentlyhavedirectconnectivity toatestenergymanagementsystemfortestingandintegratingnewscadasystems. Question3:Doesyourfacilitycurrentlyhaveaninhouserealtimedigitalsimulatorsystemfortestingof substationprotectionandautomationfunctionstofullyvetandtestnextgenerationsubstation automationsystems? SCE,alongwithtenrespondents(1,2,3,6,7,9,10,11,12,and13)currentlyhaveaninhouse realtimedigitalsimulatorfortestingofsubstationprotectionandautomationfunctionstofully vetandtestnextgenerationsubstationautomationsystems. Question4:Doesyourfacilitycurrentlyhavetheabilitytomimicalargesubstation(upto70racks)for testingofgridmodernizationequipment? Fiverespondents(1,7,8,11,and12)currentlyhavetheabilitytomimicalargesubstationfor testingofgridmodernizationequipment. Synopsis: Asthesurveyresultsshowamongthesevencategories(Controls,DistributionAutomation,Distributed EnergyResources,GridEdgeSolutions,DistributionGridAnalytics,PowerSystems,andSubstation Automation)ofSCE stestingandevaluationneeds,thereisawidespreadofcapabilitiesamongvarious entitiesandonlyfenwicklabshasallthecapabilitiestomeetsce stestingandevaluationneeds.the responsesalsoindicatethatotherlabsare1)morefocusedontestingindividualpiecesofequipment and2)focusedontestinginatraditionaldistributionenvironment.sceneedstoadditionally1) evaluatehowapieceofequipmentfeedsbackintothedistributiongrid,notjusthowtheequipment performs,2)evaluatenotjustindividualpiecesofequipmentbuttheimpactofhavingmanypiecesof equipmentattachedtothegrid.theotherconclusionwedrawfromtheseresponsesisthatfortesting moreadvancedcapabilities(e.g.sa3),thereareveryfewalternativesavailable.itismorecosteffective andefficienttousethefenwicklabs,whichisalreadyinplacewithatrainedstaff,ratherthantryingto replicatethesecapabilitiesacrossapatchworkofmultipleentities.

131 68 Workpaper Southern California Edison / 2018 GRC PomonaLab:SurveySummary Background: TodeterminewhichentitiespossessSCE sneededcapabilitiesasurveywasconductedtargeting universities,nationallabsandenergyconsortia.sce,alongwith12entitiesrespondedtothesurvey, whichwasdividedintothreecategories:electrictransportation,garageofthefuture,andenergy Storage(BatteryProfiling,Testing,andEvaluationCapabilities). ElectricTransportation:Thiscategorycontainsthefollowingsevenquestionsandeachquestion containssubquestions: Question1:Doesyourfacilityhavethecapabilitytoconductfueleconomyandemissionstestingoflight dutyvehiclesaccordingtofederalstandards?ifyes,doesthefacilityhavethecapabilitytotestand evaluatethefollowingtypesofvehicles:conventionalice,electric,hybridelectric,andgaseousfueled? SCEandrespondent5haveafacilitycapableofconductingfueleconomyandemissionstesting oflightdutyvehiclesaccordingtofederalstandardsandhavetheabilitytotestandevaluateall typesofvehicles. Question2:Doesyourfacilityhavethecapabilitytoconductheavydutyenginetestingaccordingto federalstandards?ifyes,doesthefacilityhavetheabilitytoconducttestingon:fueleconomy, emissions,hybridelectricdrivesandgaseousfuelengines? Onlyrespondent5hasthecapabilitytoconductheavydutyenginetestingaccordingtofederal standards. Question3:Doesyourfacilityhavethecapabilitytoconductfueleconomyandemissionstestingof heavydutyvehiclesaccordingtofederalstandards?ifyesdoesithavethecapabilitytotest: dynamometer,onroad,hybridelectricvehicles,gaseousfuelvehicles,pemsemissionstesting,bag emissionstesting,andstationaryutilityorothervocationalcycles? SCEandrespondent5havethecapabilitytoconductfueleconomyandemissionstestingof heavydutyvehiclesaccordingtofederalstandards. Question4:Doesyourfacilityhavethecapabilitytotestelectricvehiclesupplyequipment?Ifyes,does thefacilityhavethecapabilitytotest:saej1772levels1and2,saej1772level3ac,saej1772dcfast ChargingComboCCS,bidirectionalpowerEVSE,AC3phaseEVSE,overheadconductivepowertransfer EVSE,wirelesspowertransferEVSE,fastchargingchAdeMo,gridsimulationimpacts? SCE,alongwithsevenotherrespondents(1,3,5,7,9,11and13)havethecapabilitytotest electricvehiclesupplyequipment.respondent11possessalltheadditionaltestingcapabilities. SCE,alongwithrespondent9have89%oftheadditionalcapabilities.Respondent7has78%, Respondents5and3have67%,andRespondent1has33%oftheadditionalcapabilities. Question5:Doesyourfacilityhavethecapabilitytotestfullpluginelectricvehicle(PEV)charging systemsforeffect,efficiency,andpowerquality?ifyes,doesithavethecapabilitytotest:saej2894/2, CaliforniaTitle20,andvehicletogridsystems,IEEE1547,UL1741? SCE,alongwithfiveotherrespondents(1,3,5,11,and13)haveafacilitycapableoftestingfull pluginelectricvehiclepevchargingsystemsforeffect,efficiency,andpowerquality.sce,along withrespondents11and13possessalltheadditionalcapabilities,whilerespondent3has67% andrespondent1has33%oftheadditionaltestingcapabilities.

132 69 Question6:Doesyourfacilityhavethecapabilitytotestauxiliarypowersystems?Ifyes,doesyour facilityhavethecapabilitytotest:enginegenerators,batterypowersystems,acpowerinverter systems,dcdcpowersystems,hydraulicpowersystems,powerthermalmanagementsystems, electricalisolationandpersonnelprotection,hvacsystems,andcompressedairstoragesystems? SCE,alongwithfourotherrespondents(5,7,11and13)haveafacilitycapabilitytotestauxiliary powersystems.sceandrespondent11possessesalltheadditionaltestingcapabilities. Respondents5and13have78%,Respondent7has22%oftheadditionalequipmenttesting capabilities. Question7:DoesyourfacilityhaveinhouseCFR/EPAspecificationchassisdynamometer?Ifso,doesit havethecapabilitytotest:lightduty,heavyduty,emissionsmeasurement,pevcharginginfrastructure, gaseousfuels? SCE,alongwithtwootherrespondents(5and11)haveafacilitythatcontainsaninhouse CFR/EPAspecificationchassisdynamometer.Respondent5hasalladditionaltestingcapabilities, whilescehas67%andrespondent11has40%additionaltestingcapabilities. GarageoftheFuture:Thiscategorycontainsthefollowingtwoquestions,thefirstbeingamultipart questionandthesecondquestion,containsasubquestion: Question1:Doesyourfacilitycurrentlyoperatewiththefollowingequipmentand/orcapabilities:PV simulatorsallowingsimulationofpvorstorage(dc)interactions,energystorage,evs,dcfastcharger, rooftoppvtoallowdemonstrationandevaluationofcommunicationsandcontrolsintegration,and externalandinternalnetworkinterfacesforinterfacingwithcontrolssystems,internetbasedentities, andinternalequipment? SCE,alongwithelevenrespondentshaveafacilitythatcurrentlyoperateswiththe aforementionedequipmentand/orcapabilities.sce,alongwithrespondents2,3,4,6,8,9,11 and13haveallthecapabilities.whilerespondents7and12have67%andrespondent5has 33%ofthetestingcapabilities. Question2:Doesyourfacilitycurrentlyhavetheabilitytoevaluateandutilizeseveralmodelingtoolsto developdistributioncircuitmodels?ifso,doesyourfacilityhavetheabilitytosimulateandevaluatea virtuallyunlimitedsetofusecasesinsafeandcontrolledconditions? SCE,alongwithelevenrespondentshavetheabilitytoevaluateandutilizeseveralmodeling toolstodevelopdistributioncircuitmodels.sceandrespondents1,2,3,4,6,8,9,11,12,and 13havetheadditionalabilitytosimulateandevaluateavirtuallyunlimitedsetofusecases, whilerespondent7doesnothavetheability. EnergyStorage:Thiscategorycontainsthefollowingelevenquestions,twoofwhichhavesub questions: Question1:Doesyourfacilityhavethecapabilitytotestlargebatterysystemswithmaximumratingsof 900VDC,1000ADC,and250kWinlargetemperaturecontrolledsettings? SCE,alongwiththreeotherrespondents(4,10and13)havethecapabilitytotestlargebattery systemswithmaximumratingsof900vdc,1000adc,and250kwinlargetemperate controlledsettings. Question2:Whatisthetotalnumberofindividualtestsonlargebatterysystemsthatcanbetestedat anygiventime?

133 70 Workpaper Southern California Edison / 2018 GRC SCE,alongwithRespondents5and13canrunmorethanonetestonlargebatterysystemsat anygiventime.scehastheabilitytorun4tests,respondent13hastheabilitytorun3tests, andrespondent5hastheabilitytoruntwotests. Question3:Doesyourfacilityhavethecapabilitytotestbatteriespackswithmaximumratingsof445V DC,265ADC,and125kWinlargetemperaturecontrolledenvironments? SCE,alongwithfiverespondents(4,5,9,10and13)havethecapabilitytotestbatteriespacks withmaximumratingsof445vdc,265adc,and125kwinlargetemperaturecontrolled environments. Question4:Whatisthetotalnumberofindividualtestsonbatteriespacksthatcanbetestedatany giventime? SCE,alongwithRespondents5and13havetheabilitytoperformmultipleindividualtestson batteriespacksatanygiventime.scehasthecapabilitytorun14individualtests,while Respondents5and13havethecapabilitytorun3individualtests. Question5:Doesyourfacilityhavethecapabilitytotestbatterycellswithmaximumvoltageof5VDC and400adcintemperaturecontrolledenvironments? SCE,alongwithsixotherrespondents(1,4,5,9,10,and13)havethecapabilitytotestbattery cellswithmaximumvoltageof5vdcand400adcintemperatecontrolledenvironments. Question6:Whatisthetotalnumberofbatterycellsthatcanbetestedatanygiventime? SCE,alongwithRespondents1and5havetheabilitytotestbatterycells.SCEcantesttwo batterycellsatanygiventime. Question7:Doesyourfacilityhavethecapabilitytotestacompleteenergystoragesystemwith maximumratingsof480vac,and250kwandupto140sqftfootprintpersystem? SCE,alongwithsevenrespondents(1,4,5,9,10,11,and13)havethecapabilitytotesta completeenergystoragesystemwithmaximumratingsof480vac,and250kwandupto140 sqftfootprintpersystem. Question8:Doesyourfacilityhavethecapabilitytotestindividualcriticalcomponentsofanenergy storagesystem?suchasthepowerconversionsystems,batterymanagementsystems,andcontroland communicationsinterface? SCE,alongwitheightrespondents(1,3,4,5,9,10,11,and13)havethecapabilitytotest individualcriticalcomponentsofanenergystoragesystem. Question9:DoesyourfacilityhavetheabilitytoconductgridimpacttestingofEnergyStorageSystems (ESS)?Ifso,canyourfacilityconducttestingbyconnectingESS stothegrid?canyourfacilityconduct testingbyutilizingasimulatedgridthatcanrunprofilesforgriddisturbancesatvariousvoltageand phaseconfigurations? SCE,alongwitheightrespondents(1,3,4,9,10,11,12,and13)havetheabilitytoconductgrid impacttestingofess.sceandrespondents4,9,and11havetheabilitytoconducttestingby connectingess stothegridandutilizingasimulatedgrid.respondents1,3,10,12,and13have 50%ofthesecapabilities.

134 71 Question10:WhatisthetotalnumberofESSthatcanbetestedatanygiventime? SCEandRespondent13havetheabilitytotestmorethantheoneESSatanygiventime.SCEhas thecapabilitytotestatamaximum18essand24cells.respondent13cantest3ess. Question11:DoesyourfacilityhavethecapabilitytoconductevaluationofPhotovoltaicequipment(i.e., PVarraysandPVinverters)? SCE,alongwithninerespondents(1,2,3,4,5,9,11,12,and13)havethecapabilitytoconduct evaluationofphotovoltaicequipment. Synopsis: Asthesurveyresultsshow,thereisawidespreadofcapabilitiesthatSCEneedsamongvariousentities andonlythepomonalabhasallthecapabilitiesintransportationelectrification,vehiclecharging equipment,andenergystoragebatteryprofile,testingandevaluation.theresultsalsoshowthatthe otherrespondentsaremorefocusedontestingstorageinatraditionaldistributionenvironment,and thepomonalabisalsocapableofevaluatinghowstoragewilloperationinthegridofthefuture,which willbeamorederintensiveenvironment.asthesynergybetweenenergystoragebatterysystemsand vehiclescontinues,itwillbeimportanttouseasinglefacility.moreover,usingasinglefacilitythatis alreadyinplacewithtrainedstaffismorecosteffectivethantryingtoreplicatethesesamecapabilities amongmultipledisparateentities.

135 72 Workpaper Southern California Edison / 2018 GRC EquipmentDemonstration&EvaluationFacility:SurveySummary Background: TodeterminewhichentitiespossessSCE sneededcapabilitiesasurveywasconductedtargeting universities,nationallabsandenergyconsortia.sce,alongwith12entitiesrespondedtothesurvey, whichwascomprisedofthefollowingfourquestions: Question1:Doyoucurrentlyhaveahighvoltagedistributioncircuit(12kV35kV)facilitydedicatedto testingnewequipment? SCEandfourrespondents(9,10,12,and13)haveahighvoltagedistributioncircuitfacility. 20additionalfollowupquestionswereaskedtodeterminethetestingandevaluation capabilitiesofthehighvoltagedistributioncircuitfacility.suchquestionsincludewhetherthe facilityisintegratedwithotherdistributioncircuitsfedfromthesourcesubstation,canthe facilitytestvoltageimpactsofderswitchingdevices,doesthefacilityhaveacapabilityof simulatingvariouscircuitlengths,etc.) o Ofthe20additionalquestionsregardingcapabilities,SCE sedefhasthemost capabilitiesat90%.respondent9has85%,respondent10andrespondent13 has70%,andrespondent12has30%ofthecapabilities. Question2:Doyouhaveafacilitycapableofmonitoringtestcircuitsandthetestsperformedusingan existingdistributionmanagementsystem(dms)? SCE,alongwiththreeotherrespondents(4,9,and13)haveafacilitycapableofmonitoringtest circuitsperformedusinganexistingdms. Question3:Doyouhaveafacilitycapabilityofsimulatingvariouscircuitlengths? SCE,alongwithfourotherrespondents(4,8,10,and13)haveafacilitycapableofmonitoring testcircuitsperformedusinganexistingdms. Question4:Doyouhaveafacilitycapabilityofsimulatingdifferentcircuitconfigurations(loop,radial, network)? SCE,alongwithfourotherrespondents(8,9,10,and13)haveafacilitycapableofsimulating differentcircuitconfigurations. Synopsis: Asthesurveyresultsshow,onlytheEquipmentDemonstration&EvaluationFacilityhasallthe capabilitiessceneedsforevaluationandtestingnewequipment.theresponsesalsoindicatethatother labsare1)morefocusedontestingindividualpiecesofequipmentand2)focusedontestingina traditionaldistributionenvironment.sceneedstoadditionally1)evaluatehowapieceofequipment feedsbackintothedistributiongrid,notjusthowtheequipmentperforms,2)evaluatenotjust individualpiecesofequipmentbuttheimpactofhavingmanypiecesofequipmentattachedtothegrid. Whileotherentitiespossesssomeofthesetestingandevaluationcapabilities,itismorecosteffectiveto useasinglefacility,rathertryingtoreplicatethesesamecapabilitieswithmultipledisparateentities.

136 73 Advanced Technology Laboratories 2018 General Rate Case Program Name: Advanced Technology Laboratories Projects 1 Advanced Technology Labs - Fenwick 2 Advanced Technology Labs - Pomona 3 Equipment Demonstration and Evaluation Facility (EDEF) Total Budget (Constant Dollars $000) Total Budget $ 9,397 $ 8,342 $ 5,559 $ 7,385 $ 10,142 Total Budget - Advanced Technology Labs - Fenwick Project Component New Equipment $ 2,416 $ 2,596 $ 2,231 $ 3,087 $ 2,482 Equipment Refresh $ 1,600 $ 1,738 $ 1,600 $ 2,500 $ 5,837 Other $ 178 $ 178 $ 103 $ 103 $ 103 Fenwick Total $ 4,194 $ 4,512 $ 3,934 $ 5,690 $ 8,422 Total Budget - Advanced Technology Labs - Pomona Project Component New Equipment $ 142 $ 268 $ - $ 236 $ - Equipment Refresh $ 1,023 $ 647 $ 410 $ 244 $ 505 Other $ 440 $ 720 $ 720 $ 720 $ 720 Pomona Total $ 1,605 $ 1,635 $ 1,130 $ 1,200 $ 1,225 Total Budget - Equipment Demonstration and Evaluation Facility (EDEF) Project Component New Equipment $ 90 $ 350 $ 350 $ 375 $ 370 Infrastructure Improvements $ 3,488 $ 1,700 $ - $ - $ - Other $ 20 $ 145 $ 145 $ 120 $ 125 Total $ 3,598 $ 2,195 $ 495 $ 495 $ 495 AT Labs - 1 of 5 8/10/2016

137 74 Workpaper Southern California Edison / 2018 GRC Advanced Technology Laboratories 2018 General Rate Case Project Name: Fenwick Labs Project Components: 1 New Equipment 2 Equipment Refresh 3 Other Total Budget - Fenwick Labs Total Budget $ 4,194 $ 4,512 $ 3,934 $ 5,690 $ 8,422 New Equipment Project Component Lab Tools 1 $ 212 $ 245 $ 206 $ 206 $ 232 Substation Automation Equipment $ 202 $ 200 $ - $ - $ - Distribution Grid Analytics Equipment 2 $ 1,002 $ 987 $ 1,000 $ 1,451 $ 1,000 Controls Lab Equipment 3 $ 1,000 $ 1,003 $ 1,000 $ 1,381 $ 1,000 Visualization Hardware & Installation $ - $ 161 $ 25 $ 49 $ 250 New Equipment Totals $ 2,416 $ 2,596 $ 2,231 $ 3,087 $ 2,482 Equipment Refresh Project Component Computer/Monitor Refresh $ - $ 138 $ - $ - $ 138 Equipment Replacement 4 $ 542 $ 542 $ 542 $ 620 $ 511 HiperWall Refresh/Upgrades $ - $ - $ - $ 722 $ - Communications System Refresh 5 $ - $ - $ - $ - $ 3,012 RTDS Upgrades/Refresh 6 $ 1,058 $ 1,058 $ 1,058 $ 1,058 $ 1,058 DA Lab Equipment $ - $ - $ - $ 100 $ - Technology Transfer Center Equipment $ - $ - $ - $ - $ 1,118 Equipment Refresh Totals $ 1,600 $ 1,738 $ 1,600 $ 2,500 $ 5,837 Other Project Component Facility Improvements 7 $ 178 $ 178 $ 103 $ 103 $ 103 Other Totals $ 178 $ 178 $ 103 $ 103 $ Eight Power System Simulators, one Grid Simulator, and thirteen Electrical System Monitors to support new testing requirements. Cost estimates based on previous equipment purchases Growth in analytics within the Distribution Grid Analytics Lab (DGAL) requires the addition of three Simulation Devices, thirteen Computer Workstations, one Big Data Server, seven Data Storage Warehouses, and the expansion of Data Storage Memory. Cost estimates based on vendor quotes and previously purchased equipment. Intelligence Equipment to continue the expansion of modeling circuits including six Simulation Devices, five Data Storage Devices, and five Control System Testbeds. Cost estimates based on vendor quotes and previously purchased equipment. Purchase of new lab equipment to replace aging equipment that is beyond economic repair and keep current with technologies. Equipment to be replaced includes relays, power system simulators, high power AC/DC power source, data acquisition equipment, and electrical circuit monitoring equipment. Cost estimitates are based on vendor quotes and previously purchased equipment. Refresh of the Advanced Technology Lab Network which supports all of the Advanced Technology Labs and provides a stand alone test network outside of the SCE production system. Cost estimates based on previously purchased equipment. The purchase of additional simulation equipment and technology upgrades to expand/enhance the modeling/testing capabilities of the Power Systems Lab. Cost estimates based on previously purchased equipment. The projected annual spend to retool lab areas to expand testing capabilities. This includes minor remodeling of existing lab space, relocation of capital equipment, and purchase and installation of additional test infrastructure such as conduit, cables, electrical enclosures, and communication drops. The cost is based on similar previously purchased installation services by existing SCE vendor rates. AT Labs - 2 of 5 8/10/2016

138 75 Advanced Technology Laboratories 2018 General Rate Case Project Name: Pomona Labs Project Components: 1 New Equipment 2 Equipment Refresh 3 Other Total Budget - Pomona Labs Total Budget $ 1,605 $ 1,635 $ 1,130 $ 1,200 $ 1,225 New Equipment 1 Project Component Vehicle Data Acquisition Systems $ 52 $ - $ - $ - $ - Emissions Tester $ - $ 268 $ - $ 236 $ - Data Control Hardware & Installation $ 90 $ - $ - $ - $ - New Equipment Totals $ 142 $ 268 $ - $ 236 $ - Project Component Environmental Chambers (Standard) $ 111 $ 56 $ - $ - $ 222 Environmental Chambers (Walk-In) $ - $ - $ - $ 143 $ - Test Cyclers (High Power) $ 275 $ - $ - $ - $ - Test Cyclers (Medium Power) $ 176 $ 176 $ 176 $ - $ 176 Load Banks (Static) $ - $ - $ 80 $ - $ - Load Banks (Dynamic) $ - $ 94 $ - $ - $ 63 Grid Simulator (Low Power) $ 214 $ 212 $ - $ - $ - Grid Simulator (High Power) $ 93 $ - $ 93 $ - $ - Data Acquisition Systems $ - $ 110 $ - $ 101 $ 14 Fuel Flow Meters $ 155 $ - $ 62 $ - $ 31 Equipment Refresh Totals $ 1,023 $ 647 $ 410 $ 244 $ 505 Project Component Facility Improvements 3 $ 100 $ 90 $ 90 $ 90 $ 90 Modified Test Vehicles 4 $ 340 $ 630 $ 630 $ 630 $ 630 Other Totals $ 440 $ 720 $ 720 $ 720 $ 720 Purchase of new equipment to expand lab testing capabilities to meet current technological testing standards. New equipment includes vehicle data acquisition systems and emissions testing equipment to expand electric, conventional, and hybrid vehicle testing as well as a Data Control System to increase energy storage system testing efficiency. Estimates are based on vendor quotes and similar previously purchased products and services Purchase of new lab equipment to replace aging equipment that is beyond economic repair and to keep up with current emerging technologies. Equipment to be replaced includes energy storage system, electric vehicle infrastructure, and conventional vehicle test equipment such as environmental chambers, test cyclers, load banks, grid simulators, data acquisition systems, and fuel flow meters. Project management based the estimates on vendor quotes and similar previously purchased products and services Equipment Refresh 2 Other This includes minor remodeling of existing lab space, relocation of capital equipment, and purchase and installation of additional test infrastructure such as conduit, cables, electrical enclosures, and communication drops. Estimates are based on vendor quotes and similar previously purchased products and services. In 2016, one light-duty pickup in utility configuration and one heavy-duty service body utility vehicle will be purchased. In 2017 and 2018, two medium-heavy duty service body utility vehicles will be purchased each year. All vehicles will be converted to a plug-in hybrid-electric drive configuration with electric drive vocational equipment and be tested for electric system impact, fuel consumption, emissions reduction, and user satisfaction to help SCE determine the right technology as it electrifies its fleet. AT Labs - 3 of 5 8/10/2016

139 76 Workpaper Southern California Edison / 2018 GRC Advanced Technology Laboratories 2018 General Rate Case Project Name: Equipment Demonstration and Evaluation Facility (EDEF) Project Components: 1 New Equipment 2 Infrastructure Improvements 3 Other Total Budget - Equipment Demonstration and Evaluation Facility Total Budget $ 3,598 $ 2,195 $ 495 $ 495 $ 495 Project Component Power System Simulators 1 $ 90 $ 180 $ 180 $ - $ - Optical Isolators $ - $ 30 $ - $ - $ - Padmount Transformrs 2 $ - $ - $ 50 $ - $ - Substation Automation Equipment 3 $ - $ - $ - $ 200 $ 150 Wood Poles 4 $ - $ 15 $ - $ - $ - Inverters $ - $ - $ - $ 100 $ 145 Reclosers 5 $ - $ 50 $ - $ - $ - Resistor Cabinet 6 $ - $ - $ 45 $ - $ - Data Acquisition Systems 7 $ - $ 75 $ 75 $ 75 $ 75 New Equipment Totals $ 90 $ 350 $ 350 $ 375 $ 370 Project Component Control Room Construction 8 $ 2,246 $ 763 $ - $ - $ - Site Improvements 9 $ 260 $ - $ - $ - $ - Equipment & Installation 10 $ 240 $ 937 $ - $ - $ - LESTA Integration 11 $ 742 $ - $ - $ - $ - New Equipment Totals $ 3,488 $ 1,700 $ - $ - $ - Project Component Facility Improvements 12 $ 10 $ 100 $ 100 $ 75 $ 80 Capital Contingency 10% $ 10 $ 45 $ 45 $ 45 $ 45 Other Totals $ 20 $ 145 $ 145 $ 120 $ Five Power System Simulators to expand testing and simulation capabilities. The estimate is based on existing purchase orders. 2 Two 1,000 kva and one 225 kva Pad-Mount Transformer to expand the number of test stations based on existing SCE material cost sheets. 3 Installation of Substation Automation Equipment to expand test capabilities. Includes the cost of relays, annunciators, switches, and a common substation platform, based on existing invoices from vendors New Equipment Infrastructure Improvements Other Material cost for ten Class 2 Wood Poles to extend the overhead line based on existing SCE material cost sheets. Two 600 AMP reclosers to extend overhead line based on existing SCE material cost sheets. Resistor Cabinet to expand fault test pad based on existing invoice from the vendor. Two Data Acquisition Systems per year to support new test beds based on existing purchase order with the vendor. Construction of the EDEF Control Building based on an estimate from an existing SCE contractor. Construction of a block wall on the south side of the facility to improve security. Based on existing invoices from contractor. Installation of a Security System including access control, closed circuit television, and intercom system. Includes the purchase and installation of one 0.5 MW Grid Simulator system to expand testing and simulation capabilities. The forecast is based on existing vendor quotes. Construction, material, and labor costs to integrate the Large Energy Storage Testing Apparatus into EDEF. The labor cost includes SCE electrical crews, general contractors, and electricians. Annual amount anticipated to be spent to accommodate expansion of testing equipment and apparatuses. Installation of wood poles, transformers, reclosers, resistor cabinet, data acquisition systems, mentioned in footnotes 2-7 and other devices. The cost are based on similar previously h d i t ll ti i b i ti SCE d t d i l d l b t f SCE Di t ib ti C AT Labs - 4 of 5 8/10/2016

140 77 Advanced Technology Laboratories 2018 General Rate Case purchased installation services by existing SCE vendor rates and includes labor costs for SCE Distribution Crews. AT Labs - 5 of 5 8/10/2016

141 78 Workpaper Southern California Edison / 2018 GRC

142 79 FINAL REPORT for the RESEARCH AND DEVELOPMENT OF SPREAD SPECTRUM TIME DOMAIN REFLECTOMETRY FOR HIGH IMPEDANCE FAULT DETECTION IN AN ELECTRICITY DISTRIBUTION SYSTEM PHASE 2A ETENSION (SSTDR HIZ) May 25, 2016 SwRI Project No Extension Prepared for Southern California Edison Fenwick Plaza Chestnut Street Westminster, CA Prepared by SOUTHWEST RESEARCH INSTITUTE Automation and Data Systems Division 6220 Culebra Road, San Antonio, Texas (210) FA (210)

143 80 Workpaper Southern California Edison / 2018 GRC

144 81 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page ii EECUTIVE SUMMARY Incidental high impedance faults are not detected and isolated by conventional means and represent a hazard to unsuspecting bystanders and utility workers. Incidental faults have been shown to occur at a rate of one fault per line every four years. High impedance faults become regular occurrences in large distribution or feeder line systems. This anomaly impedance discontinuity detector project, through Phase 1 and Phase 2A research and development, has demonstrated that Spread Spectrum Time Domain Reflectometry can be utilized to detect conditions on power distribution lines which can indicate the location of high impedance faults. Phase 2A Extension Project Goals Demonstrate ability to detect a broken-phase anomaly between a transformer and the power source Modify the system to monitor three-phase power conductors Test the system on energized conductors Develop and document a design for building a field prototype Further refine and enhance the system Phase 2A Project Results Phase 2A saw several landmark accomplishments in the development of the HiZ system. The system, which had previously been limited to benchtop testing, was tested on outdoor conductor line. Testing was able to successfully determine when a single-phase unenergized line was dropped or drooped onto the ground. Testing progressed onto an energized line, where the system successfully demonstrated the ability to detect anomalies in an energized environment. The system was successfully converted to be able to detect anomalies in a three-phase environment. Three-phase energized testing was performed at 4 kv and 12 kv and successfully demonstrated the capability to detect anomalies. Transformer backfeed detection was investigated and it was determined that, while the system cannot detect anomalies through the transformer, anomalies will be detected on the phase in which they occur. A prototype for Phase 2B was designed and a bill of materials was created. Anomaly detection algorithms and other software improvements were made and continue to improve the performance of the system. The significant progress of the HiZ system in this phase gives the team high confidence of success going into Phase 2B. Recommendation Based on the progress of the Phase 2A extension development and testing, we feel the technology is ready to move into a prototype development phase specifically focused on topics such as: Building a prototype suitable for a field demonstration Interfacing to SCADA for data integration Integrating map changes for (OMS/DMS) line configuration changes

145 82 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page iii TABLE OF CONTENTS 1. Document Summary Background Information Reference Documents Project Goals Project Goal 1 Transformer Backfeed Detection Investigation Project Goal 2 Multi-Phase Monitoring and Anomaly Detection Project Goal 3 Expanded Field Testing Project Goal 4 Prototype Design Project Goal 5 Continued Improvements Project Results Project Result 1 Transformer Backfeed Detection Investigation Project Result 2 Multi-Phase Monitoring and Anomaly Detection Project Result 3 Expanded Field Testing Project Result 4 Prototype Design Project Result 5 Continued Improvements Laboratory Research Environment Field Test Environments Short Line Field Testing Long Line Field Testing EDEF Field Testing Concept of Operation Purpose System Configuration Reflection Calibration Operation Detection Alerting Line Configuration Changes Research Details And Results Transformer Backfeed Detection Investigation Research Results and Observations Multi-Phase Monitoring and Anomaly Detection Multi-Phase Monitoring Design and Implementation Results and Observations Expanded Field Testing... 21

146 83 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page iv Test Environments SwRI Field Site Sabinal Field Site EDEF Test Site Field Testing Results and Observations Prototype Design Requirements Definitions Research Results and Observations Continued Improvements Anomaly Detection Chirps Peripheral Box Conclusion References APPENDI A: Acronyms and Definitions... A-1

147 84 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page v LIST OF FIGURES Figure 1. The HiZ Research Environment for Three-Phase Monitoring... 6 Figure 2. HiZ System with Coupler Switch Box... 7 Figure 3. PI, Coupler, and Amplifier Setup... 8 Figure 4. Coupler Switch Box... 8 Figure 5. Connections for the Switch Box... 9 Figure 6. SwRI Short Line Field Test Site Figure 7. Energized Short Line Test Setup at SwRI Field Site Figure 8. Aerial View of Sabinal Long Line Test Facility Figure 9. Line View of Sabinal Test Facility Figure 10. One Line of EDEF Test Site Showing Circuit Path for HiZ Testing Figure 11. Initial Setup Screen Figure 12. Hardware Setup Screen Figure 13. Operational Mode Screen Figure 14. 4kV Transformer Figure 15. Transformer Nameplate Figure 16. Prototype Design Block Diagram... 23

148 85 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 1 1. DOCUMENT SUMMARY This document presents the results of research, development, and testing of anomaly high impedance discontinuity detection capability that was conceptually proven in a Phase 1 project, was further enhanced and tested in Phase 2A, and has been subsequently developed and tested further in this Phase 2A extension project. Section 2 provides a background of the project Section 3 lists previous project related documents utilized and/or produced during this project Section 4 introduces the goals of this Phase 2A project Section 5 provides the team s results in working toward each goal Sections 6 & 7 discuss the equipment and testing environments used in this phase Section 8 provides a concept of operations for the HiZ system Section 9 provides detailed research summaries for each project goal Section 10 provides a conclusion and some recommendations

149 86 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 2 2. BACKGROUND INFORMATION Incidental high impedance faults are not detected and isolated by conventional means and, as such, represent a hazard to unsuspecting bystanders and utility workers. Incidental faults have been shown to occur at a rate of one fault per line every four years. High impedence faults become regular occurrences in large transmission or feeder line systems. For example, a studied system of 260 feeder lines produced an average of 35 high impedance faults per year. The current fault detection state of commercialization has a 58% fault detection rate accompanied by a 2% false alarm rate and a 40% detection failure rate. Clearly, there is a need for a more dependable method of detecting high impedance faults. Southwest Research Institute (SwRI ) has conducted previous work in the field of using Spread Spectrum Time Domain Reflectometry (SSTDR) to solve problems in measurement, localization, and anomaly impedance discontinuity detection. Through our previous experience, we believed that by enhancing SSTDR for use in an electrical distribution system, we could develop distance measurement techniques for detecting and localizing high impedance faults. In Phase 1 research that concluded in December 2014, SwRI demonstrated a proof-of-concept project utilizing SSTDR technology and distance measurement techniques to detect anomaly impedance discontinuity conditions on distribution lines. The project demonstrated how SSTDR was able to detect and locate anomaly impedance discontinuity faults by applying a carefully constructed signal to the distribution line and observing the reflections. Phase 1 validated the accuracy, robustness, and reliability of the impedance discontinuity localization techniques in a manner sufficient to proceed to a more detailed research and development phase with expanded testing on distribution line. In Phase 2A, further research was conducted to refine the techniques and algorithms for signal generation, reflection processing, map building, and reflection mapping. Research was conducted on in-line coupling technology, and an existing technology in the market was identified which is suitable for the project s needs. A draft test plan for un-energized and energized testing was developed. Repeated testing (single phase) was conducted on various exterior un-energized power lines utilizing the selected in-line (capacitive) coupler. Methods to translate circuit maps from SCE geographical information systems into workable data structures for anomaly localization, as well as self-learning techniques for reacting to power flow configuration changes, were developed and tested. The technology was tested on increasingly complex representations of distribution circuits, culminating in testing at the SCE Chino Climbing Facility. For this Phase 2A extension, the system was further enhanced to move from single phase monitoring to three-phase monitoring. The system was converted from manual control to an automated operational system with continuous monitoring. A controllable switch box was developed that allows one set of computing and signal hardware to control signal input and signal receipt on three independent line couplers. Extensive field testing was conducted on energized lines, starting at 120 VAC going up to 4 kv three-phase distribution. Testing of signal propagation through a phase-to-phase transformer connection was conducted. Initial conductive coupling testing on underground conductors was done. Testing of impedance discontinuities was done with placement before and after the transformer connections, as well as on the phase not connected to the transformer. Utilizing the development work done to accomplish this phase, a design document for a field prototype was developed. Finally, the system was demonstrated at the EDEF test facility at the Shawnee Substation in Huntington Beach, California. The results of this extension project demonstrate that the HiZ system is capable of detecting anomaly impedances on energized circuits in a wide variety of system conditions. We believe the technology is ready for further prototype development for field testing.

150 87 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 3 3. REFERENCE DOCUMENTS The following documents were incorporated without reference into the work of this Phase 2A Extension project: White Paper on High Impedance Fault Detection and Localization. SwRI; 13 December, Presentation for SCE Meeting at SwRI. SwRI; 31 March Final Report for the Research and Development of Spread Spectrum Time Domain Reflectometry For High Impedance Fault Detection In An Electricity Distribution System (SSTDR HIZ). SwRI; 16 December, Proposal for Research and Development of Spread Spectrum Time Domain Reflectometry for High Impedance Fault Detection in an Electricity Distribution System, Phase 2A. SwRI; 6 March, System Demonstration Test Plan for Spread Spectrum Time Domain Reflectometry HIZ System. SwRI; 28 April, Coupling Technology Report for Spread Spectrum Time Domain Reflectometry for Fault Detecting in an Electricity Distribution System Phase 2A. SwRI; 15 June, Final Report for the Research and Development of Spread Spectrum Time Domain Reflectometry for High Impedance Fault Detection In An Electricity Distribution System Phase 2A (SSTDR HIZ). SwRI; 15 December, De-Energized Droop Test Results for Phase 2A. SwRI; 3 February, Energized Armory Single Phase Test Plan for Phase 2A. SwRI; 15 February, Unenergized Transformer Test Plan for Phase 2A. SwRI; 11 February, Energized Single Phase Sabinal Test Plan for Phase 2A. SwRI; 18 February, Inductive Coupler Test for Phase 2A. SwRI; 11 March, Energized Three Phase Sabinal Test Plan for Phase 2A. SwRI; 24 March, Energized Three Phase Sabinal Test Plan for Phase 2A (SCE Witnessed). SwRI; 29 March, High Impedance Fault Test Procedures (EDEF Testing). SwRI; 22 April, Prototype Design of Spread Spectrum Time Domain Reflectometry for Fault Detecting in an Electricity Distribution System. SwRI; 6 May, 2016

151 88 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 4 4. PROJECT GOALS The goals for this Phase 2A project were focused in further research and development of the technology and techniques to refine the capabilities proved in Phase 1 of the HiZ program. Successful accomplishment of these stated goals provided strong proof that the program is ready to proceed to prototype development stage. 4.1 Project Goal 1 Transformer Backfeed Detection Investigation Goal: Investigate HiZ ability to detect an impedance discontinuity on a phase connected to a potential transformer where the impedance is located between the transformer and the power source. Electrical backfeed through a phase-to-phase transformer to a broken line between the transformer and the power source is a significant safety issue. It would be a significant accomplishment if the HiZ system could detect this condition through its monitoring and alert that the condition exists. This research will look further into signal propagation through a phase-to-phase transformer connection, as well as methods that HiZ could implement to accurately detect and report this dangerous condition. 4.2 Project Goal 2 Multi-Phase Monitoring and Anomaly Detection Goal: Enhance the system from single-phase monitoring to three-phase monitoring. Distribution lines at the medium voltage level are typically three-phase from the substation. The HiZ system needs to be able to monitor and detect anomaly impedances that are on any of the three phases. This development will expand the system to three-phase detection by incorporating line couplers placed on each phase, with appropriate system hardware to extend monitoring and detection to all three phases. 4.3 Project Goal 3 Expanded Field Testing Goal: Test the system on energized circuits and on three-phases. The focus of this goal is to expand testing to energized power lines, as well as to test system ability to monitor all three phases of a medium voltage distribution line. 4.4 Project Goal 4 Prototype Design Goal: Finalize a prototype design and prepare a bill of materials to ready for Phase 2B development. Based on work to this point including three-phase monitoring and detection, prepare a prototype design document that outlines how the system will be reduced to a field-deployable unit from the current laboratory-grade equipment. 4.5 Project Goal 5 Continued Improvements Goal: Continue to enhance and refine system performance. The focus of this task is to continue to improve the system in the areas of signal transmission, reflection processing, anomaly detection, and other areas based on outcomes from the expanded field testing.

152 89 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 5 5. PROJECT RESULTS The results achieved during this phase of research have met or exceeded most of the goals discussed in the previous section. These results were achieved through the algorithms and methodologies developed during this phase of the project. 5.1 Project Result 1 Transformer Backfeed Detection Investigation Testing in the laboratory on a phase-to-phase distribution transformer determined that the HiZ signal cannot effectively transmit through the transformer; that is, the signal attenuates too much to be effectively detected through the non-signal transmitted phase connected to the transformer. That being said, however, the HiZ system is able to effectively detect a broken line between the transformer and the power source. It does this because it is monitoring all three phases of the power line independently through its round-robin detection scheme. Testing showed that the system detects an impedance discontinuity on any phase, no matter where it is located. It should be noted that while the HiZ system is able to detect the broken line on the non-transmit phase of the transformer, it is not able to detect if the line from the transformer to the break is energized. This means that it is not able to detect if power is being back fed to the broken line through the transformer. 5.2 Project Result 2 Multi-Phase Monitoring and Anomaly Detection A coupler switch box was designed, constructed, and tested that allows one set of computing and signaling hardware to interact with three couplers in a round-robin manner. The box contains a digitally controlled switch to control which coupler sends the transmit signal. Testing on a three-phase circuit has proven that the coupler switch box was successfully able to control transmission and receipt of HiZ signals to a coupler on each phase of the circuit. The software of the HiZ system was modified for three-phase monitoring. Additionally, the ability to operate continually was developed, with the system able to continually monitor each phase of the circuit. 5.3 Project Result 3 Expanded Field Testing Multiple field tests were conducted at energized voltages up to 12 kv. As predicted through earlier analysis, there is no significant impact to the HiZ signal or its ability to detect anomaly impedances when the line is energized. 5.4 Project Result 4 Prototype Design Based on the work done through this phase of work, a design document for a prototype HiZ device was developed. This design incorporates the coupler switch box as a component of the system and identifies the design of the computing, signal processing, and anomaly processing components that will move the system from laboratory-grade equipment to less expensive and more ruggedized equipment suitable for field deployment. 5.5 Project Result 5 Continued Improvements As a component of the three-phase monitoring, the anomaly detection component was upgraded to utilize long-term and short-term averages to look for changes in the line that may indicate impedance anomalies. The development of these trend windows will be important as the system matures and moves to more complex line environments to reduce or eliminate false positive readings that may be caused by events such as weather, capacitor banks, switch gear, or other short-term events that may look like anomalies but, in fact, are not.

153 90 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 6 6. LABORATORY RESEARCH ENVIRONMENT Commercial off-the-shelf (COTS) equipment was utilized in order to perform the experiments in this project. The system is a PI Express controller from National Instruments which includes two digitizers, a signal generator, an analog/digital input/output device, and a computer. This hardware is programmed using LabVIEW software, which allows developing custom programs, algorithms, and data manipulation routines. Dual directional couplers were selected to isolate the transmit signals and the reflected signals going into the digitizers. A broadband amplifier is placed before the directional couplers and after the arbitrary waveform generator in order to amplify the signal to 1 W. A low noise amplifier is utilized after the reflected signal portion of the directional coupler and before the digitizer to amplify the reflected signal and match the digitizer voltage range. The antennas are used to capture noise from the atmosphere and radiated emissions from the capacitive coupler. Figure 1 shows a block diagram representative of the research environment for a system that monitors three conductor phases. Figure 2 shows how the components are distributed between the computing environment and the coupler switch box. Figure 3 shows a picture of the system as it was configured for single phase testing. Note that the components shown outside of the PI have now been relocated to the switch box. Figure 4 and Figure 5 show the switch box that enables the one set of computing hardware to interact with the three couplers. Figure 1. The HiZ Research Environment for Three-Phase Monitoring

154 91 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 7 Figure 2. HiZ System with Coupler Switch Box

155 92 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 8 Figure 3. PI, Coupler, and Amplifier Setup Figure 4. Coupler Switch Box

156 93 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 9 Figure 5. Connections for the Switch Box

157 94 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page FIELD TEST ENVIRONMENTS Several field test environments were utilized to support the research and development of the HiZ system. These environments served two primary purposes: to gather information on HiZ performance on power lines outside of the laboratory environment, and to iteratively test the HiZ system as it was being developed. 7.1 Short Line Field Testing The short line field test site, shown in Figure 6, is located on the grounds of SwRI. Figure 6. SwRI Short Line Field Test Site For this extension project, an approximately 100 meter (m) section of 336 ACSR was strung along 19 tripod structures. The line was insulated from contact with the tripods using electrical PVC conduit. The line is elevated approximately meters above ground. Using this setup, SwRI was able to conduct both de-energized testing of a longer section of line than previously, as well as testing at 120 VAC as an initial energized test.

158 95 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 11 Figure 7. Energized Short Line Test Setup at SwRI Field Site SwRI further modified the line setup to create three line sections of 336 ACSR approximately 45 meters in length. These were set up in three side-by-side sections on the same tripods. This setup was put in place for testing of the three-phase monitoring capability. 7.2 Long Line Field Testing The long line field test site shown in Figure 8 consists of a three-phase energizable conductor located approximately 60 miles west of San Antonio in Sabinal, Texas. The site has a one mile straight line conductor configuration, as shown in Figure 9, with an additional 1/3 mile feeder line to the utility connection. The line is 4/0 ACSR in a three-phase plus neutral configuration that can be energized to 14 kv. In a de-energized configuration, the phases can be crossed to create a three mile single phase. The site provides a distribution-grade conductor for testing where anomaly impedance discontinuities can be introduced and analyzed. The site does not include any equipment installed on the lines. For this phase, the line was energized at 480 VAC and then at 4 kv. A phase-to-phase distribution transformer was installed just before the line mid-point.

159 96 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 12 Figure 8. Aerial View of Sabinal Long Line Test Facility Figure 9. Line View of Sabinal Test Facility Where the short line test site was focused on understanding the behavior of the HiZ signals on power conductors, the long line test site provided a clean line environment for focusing on detecting anomaly impedances discontinuities. Results from testing at the site were used to further refine the signal processing and anomaly detection algorithms. 7.3 EDEF Field Testing The EDEF Testing Site is located at the Shawnee Substation in Huntington Beach, CA. This SCE-owned facility features an energizable test environment, shown in Figure 10, consisting of three-phase

160 97 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 13 distribution lines above and underground. There are multiple switches and reclosers installed, as well as other types of representative equipment for a distribution environment. This site represents a more realistic view of a distribution system, although it is overly congested due to physical space limitations.

161 98 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 14 Figure 10. One Line of EDEF Test Site Showing Circuit Path for HiZ Testing Testing at the EDEF site allowed for full system testing of the HiZ system, including monitoring on three phases, and the detection of different high impedance fault conditions.

162 99 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page CONCEPT OF OPERATION This section describes the basic concept of operation of the HiZ system for automated three-phase monitoring and detection. 8.1 Purpose The HiZ system being developed is designed to find anomaly impedance discontinuities on a distribution circuit. Anomaly impedance discontinuities are defined as being impedance mismatch points that do not align to impedance discontinuity points learned at startup. The system works by sending high frequency signals into a power conductor and recording reflections of that signal caused by impedance mismatches, such as taps, switches, reclosers, and other line equipment. Once an anomaly is detected, the system attempts to localize the anomaly in accordance with a circuit map, identifying the line or equipment where the anomaly occurred, the equipment just before the anomaly, and the approximate distance between them. This information would then be utilized by a line crew to travel to and find the anomaly condition. 8.2 System Configuration The system is configured by loading a circuit map for the circuit being monitored. This map is currently expected to be based on IEC RDF standards. Currently there is no other configuration required, although that may change as the system moves toward field prototype. 8.3 Reflection Calibration The next step in preparing the system for operation involves calibration of reflections from the circuit to the circuit map. For this step, it is assumed that the circuit does not have any anomaly impedance discontinuities. The system sends signals into the line, reads the reflections, and then matches them to the map. Once the system is satisfied that it has mapped all the reflections, it is ready for operation. It should be noted that this process is capable of identifying issues with the accuracy of the circuit map, and, thus, can serve a secondary function of identifying circuit maps that need updating. The HiZ system can still operate with an incorrect circuit map, since this process is to build a reflection map to be used as a trust map for operation; however, it may not be able to provide accurate equipment identification or anomaly location if the circuit map is not current. 8.4 Operation The system is operated in a set of automated steps that: Pulse a signal on a phase of line and read in the reflections Process the reflections data to discover the first anomaly reflection (if one exists) Map the anomaly to the physical map Repeat on each phase individually in a continuous loop A front panel graphical user interface has been developed to co-locate these functions such that they can all be done, and the processing results viewed, from one application. This user interface would not be a component of the final design, but is useful during these development stages to show the system working and to assist in changing parameters for testing. The system is controlled through a LabVIEW virtual instrument user interface. The user interface consists of three phases: initial setup, hardware testing and configuration, operational mode. In the initial setup screen, which phases to test on, necessary folder paths, and operation parameters are specified. A screen shot of initial setup is shown in Figure 11.

163 100 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 16 Figure 11. Initial Setup Screen

164 101 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 17 The hardware screen allows configuration of the oscilloscopes and amplifiers in the system. Parameters such as max input voltage, variable gain, and samples to record are set here. A screenshot of the hardware configuration tab is shown in Figure 12. Figure 12. Hardware Setup Screen In the operational mode screen shown in Figure 13, controls for starting and stopping the system are available. When the system is running, signals will be transmitted down a single phase and received data will be recorded for all three phases. The system then moves onto the next phase and transmits a signal down the single phase and records data from all three phases. Data received for each of the three phases is used to calculate long-term trends, short-term trends, and anomalies. The long-term data and anomalies are plotted. This continues until the user stops the system.

165 102 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 18 Figure 13. Operational Mode Screen The operational mode implements a monitoring mode, where the current snapshot of the system is compared to previous snapshots to determine if an anomaly is present. If an anomaly is detected, it is indicated on the graphs. In the above figure, anomalies are shown with a vertical red line 8.5 Detection Alerting Upon detection of an anomaly reflection, the system calculates the location of the anomaly based on the signal strength of the reflection that was anomalous. This is converted into a distance from signal injection point, which is applied to a processed circuit map in order to detect the location of the anomaly. The equipment ID of the location, typically an overhead distribution line, is retrieved from the map. Once the anomaly is mapped, the circuit map is walked backward to the nearest equipment prior to the anomaly point and a distance calculated from that equipment to the anomaly. The circuit map is also walked forward to find the next identifiable piece of equipment that is after the anomaly. This information, the equipment where the anomaly occurred, the equipment directly before the anomaly, the distance from the before equipment and the anomaly, and the equipment directly after the anomaly are then reported to localize the anomaly. 8.6 Line Configuration Changes Line configurations are capable of two types of changes: a change in the status of switchable equipment has changed the flow configuration of the line; or a physical change has been introduced into the circuit, such as a new transformer being added. Either of these conditions results in changes that require the system to relearn the circuit topography in order to identify future anomalies. In the case of a switchable equipment status change, that change would be reported to the system via a SCADA interface identifying the equipment and its new status. The HiZ system would change that status

166 103 Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page 19 in its copy of the circuit Resource Description Framework (RDF) map and rebuild its circuit data structures taking into account this circuit flow change. In the case of new line construction changes, such as new equipment, a new RDF file showing the circuit with the change would be downloaded through an interface to the HiZ system. HiZ would then rebuild its circuit data structures with this new RDF file. After either case, the system would enter into a relearning mode where it would pulse the line multiple times to develop a reflection map of the circuit in its new configuration. After it has built a reliable reflection map, it would go into its normal anomaly detection mode. For the current phase of development of the system, RDF files representing multiple switch configurations have already been pre-loaded into the HiZ system, and the appropriate one is loaded for a corresponding test. If an RDF does not exist or has not been loaded for a test, only distance from the signal injection point is reported. Changes to automate line configuration changes via an interface are planned for Phase 2B.

167 104 Workpaper Southern California Edison / 2018 GRC Southwest Research Institute SwRI Project No Extension SSTDR Phase 2A Extension May 25, 2016 Final Report Page RESEARCH DETAILS AND RESULTS This section describes more in-depth technical detail of the project. 9.1 Transformer Backfeed Detection Investigation The scope of this task was to determine the ability of HiZ to detect a broken line on one phase of a transformer when the break is between the transformer and the electricity source (i.e. substation). Our first task was to analyze the signal attenuation of the HiZ signal through the primaries of the transformer Research A 4 kv to 240/120 VAC transformer (shown in Figure 14; nameplate in Figure 15) was procured and was brought into the laboratory. Capacitive couplers were attached to each of the primary side connections to allow a signal to be injected through one side of the primary and to be received through the other side; in effect, listening to the signal that transited through the primary windings of the transformer. This duplicates the scenario where the signal is sent on Phase A and is listened to on Phase B, assuming that A and B are the two phases connected to the transformer. A resistor was placed on the secondary side to match the impedance of the capacity couplers, which allowed for maximum transmission of the signal through the transformer. Figure 14. 4kV Transformer Figure 15. Transformer Nameplate Results and Observations Testing confirmed that the HiZ signal attenuates significantly through the primary windings of the transformer such that the system is unable to accurately detect impedance anomalies that are on the other side of the winding from the transmit signal. Details of this testing are contained in the Unenergized Transformer Test Report.