The CalSolarResearch website provides information about the California Solar Initiative (CSI) Research, Development, Demonstration, and Deployment (RD&D) Program activities, including the program’s history and current CSI RD&D solicitations. Please check back regularly for updates!
CSI RD&D Final Project Webinar:
Webinar Registration Link: http://attendee.gotowebinar.com/register/6049761840273278724
This webinar will present the results of the Electric Power Research Institute (EPRI) team’s project funded under the Solicitation 4 of the CSI RD&D Program. The EPRI team which included National Renewable Energy Laboratory (NREL), and Sandia National Laboratories (SNL) with data provided from Pacific Gas and Electric (PG&E), Southern California Edison (SCE), and San Diego Gas and Electric (SDG&E) conducted research to determine optimal default settings for distributed energy resource smart inverter controls. The inverter functions studied are aligned with those developed by the California Smart Inverter Working Group (SIWG) and those being considered by the IEEE 1547 Working Group. The webinar will describe how electric utilities can leverage system information to ascertain the optimal default settings for smart inverters that will allow increased hosting capacity of distributed PV on the transmission and distribution system.
After registering, you will receive a confirmation email containing information about joining the webinar.
The University of California, San Diego (UC San Diego) and its partners developed, improved, and demonstrated solar power grid integration models. At the broad system level, relevance of solar forecasting to resource adequacy was demonstrated at very high penetration levels based on a characterization of meteorological conditions when large aggregate solar ramps are likely occur. This effort included a number of different areas: • Task 2: Demonstrating forecast performance during meteorological conditions with greatest impact on SDG&E operations and recommending monitoring improvements: Variability in solar irradiance across the San Diego Gas & Electric (SDG&E) territory informed the partitioning of solar climate zones that can be leveraged to optimize ground station coverage and solar plant allocations. • Task 3: Day-Ahead Solar forecast models for marine layer clouds: A well-known but often poorly forecast California-wide phenomenon is the burn-off of marine layer clouds. These clouds can cover a large fraction of rooftop PV systems throughout California. The project team developed forecasting tools through a combination of very high resolution numerical weather prediction, statistical modeling, and dense measurement infrastructure installed by SDG&E. • Task 4: Localized Solar Forecasting and Distribution Feeder Modeling: distribution feeder power quality analysis was forced with total sky imager cloud maps and forecasts to identify voltage control needs under high PV penetration. The modeling was conducted on five representative feeders with variations in PV penetration, location / meteorology, and voltage regulation equipment. When realistic PV input profiles are used tap operations were reduced substantially compared to using the same profile for all PV systems on the feeders. • Task 5: Forecast Integration with Utility Models for Resource Adequacy: For these same feeders net load forecast models were also developed and validated. Solar variability was found to significantly influence net load fore
Two CSI RD&D Final Project Webinars:
Webinar Registration Link: https://attendee.gotowebinar.com/register/8169543285948101377
This webinar presents analytical and experimental work performed by GE and PG&E to evaluate the likelihood of unintended islanding of solar photovoltaic (PV) inverters in distribution applications under realistic field conditions.
Most PV inverters used in distribution applications in the United States today are certified to UL 1741, which ensure that an individual inverter can detect islanding and de-energize within 2 seconds when it is coupled to a defined synthetic load. Realistic conditions in actual distribution circuits, however, are never matching the exact conditions of the UL test – the field conditions generally involve inverters of different makes and models and loads of greater variety than the synthetic load used in the UL anti-islanding test. This raises concerns about feasibility of islanding detection in realistic system conditions and poses the question: What is the maximum level of penetration that can be safely allowed on actual distribution circuits?
GE and PG&E undertook a three-year study to answer this question by performing experimental work using actual PV inverters and the flexible load specifically designed to enable streamlined evaluation of different load compositions. The flexible load uses a power electronic inverter to simulation distribution load in real time based on WECC’s composite load model executing on a Real Time Digital Simulator (RTDS). This enables evaluating loads of different compositions to more closely represent load variety found on distribution circuits in PG&E service territory.
Webinar Registration Link: https://attendee.gotowebinar.com/register/3077174972957233922
The Electric Power Research Institute (EPRI), National Renewables Energy Laboratory (NREL), and Sandia National Laboratory (SNL) will be presenting a final webinar on the Methods for Screening Distribution Feeders: Alternatives to the 15% Rule project. The objective of this project was to improve the utility application review and approval process for interconnecting photovoltaics (PV) to the utility distribution system. Working with the three investor-owned utilities, the project team evaluated the impacts of PV on the distribution system through detailed hosting capacity analysis. The results of this analysis led to the identification of additional fast-track initial and supplemental review screens that could be applied alongside the existing California Electric Rule 21 screens. These new screens are derived directly from our technical analysis and will better predict the amount of PV that can be accommodated on a feeder regardless of its loading.