In response to the US president’s declaration of a national emergency due to the coronavirus (COVID-19) pandemic, on March 20 the Pipeline and Hazardous Materials Safety Administration (PHMSA) issued a notice to operators stating that, effective immediately and until further notice or modification, PHMSA does not intend to take any enforcement action with respect to operator qualification (OQ) and control room management (CRM) requirements, and will consider exercising enforcement discretion regarding certain drug testing requirements.
The Pipeline and Hazardous Materials Safety Administration’s (PHMSA’s) long-awaited final rule on the minimum safety standards for underground natural gas storage facilities (UNGSFs) was published in the February 12 Federal Register. The final rule amends the pipeline safety regulations applicable to depleted-hydrocarbon reservoirs, aquifer reservoirs, and solution-mined salt caverns used to store natural gas. These pipeline safety regulations were established in an interim final rule that PHMSA issued in December 2016 in response to a recent significant gas leak and the mandate in the Protecting Our Infrastructure of Pipelines and Enhancing Safety Act of 2016 (the PIPES Act). The PIPES Act directed PHMSA to establish minimum safety standards for depleted-hydrocarbon reservoirs, aquifer reservoirs, and solution-mined salt caverns used to store natural gas. The final rule becomes effective March 13, 2020.
Join Morgan Lewis lawyers for these upcoming programs:
EBA Primer Series: Cybersecurity in the Energy Industry
December 09, 2019
Participants: Arjun Prasad Ramadevanahalli
Energy Storage: Regulatory, State, and Transactional Developments
December 12, 2019
Participants: Neeraj Arora , Kenneth M. Kulak , Levi McAllister
Electrifying the Transportation and Building Sectors in the PJM Footprint
December 18, 2019
Participants: Kenneth M. Kulak, Stephen M. Spina
FERC issued guidance on October 17, 2019, that may significantly aid hydroelectric developers in planning and siting potential projects. FERC issued a list, jointly developed with the secretary of the US Army, secretary of the US Department of the Interior, and secretary of the US Department of Agriculture (collectively, the Secretaries), of 230 existing nonpowered federal dams that FERC and the Secretaries agree have the greatest potential for nonfederal hydropower development. FERC also issued guidance to assist applicants for licenses or preliminary permits for closed-loop pumped storage projects at abandoned mine sites. These actions fulfill FERC’s requirements under the America’s Water Infrastructure Act of 2018 (AWAI) and are intended to encourage development of renewable energy resources by developing hydroelectric power at sites where the addition of hydroelectric capabilities would not add significant additional environmental impacts.
FERC recently issued a pair of orders approving the electric storage market participation proposals of PJM Interconnection, Inc. (PJM) and Southwest Power Pool, Inc. (SPP). PJM and SPP submitted those proposals to comply with the directives of Order No. 841, FERC’s final rule addressing the participation of electric storage resources in the capacity, energy, and ancillary service markets operated by independent system operators and regional transmission organizations. The October 17 orders represent the agency’s first two approvals of Order No. 841 compliance filings, which have been under review since late last year.
Morgan Lewis energy partner Ken Kulak takes a look at the role of regulation in defining the future of energy storage in Energy Policy Now, a podcast produced by the University of Pennsylvania Kleinman Center for Energy Policy. Ken also previews an upcoming FERC meeting during which the agency will consider plans submitted by regional transmission organizations to facilitate the participation of battery storage.
Interest in microgrids is on the rise in the United States as over half of states explore ways to modernize the grid and promote distributed energy resources (DER), including innovative renewable energy, storage, and demand response technologies. However, microgrids are not defined by law or regulation in most states and are more complex than other types of DER because they involve both the generation and distribution of energy. This raises several policy questions, including who should pay for microgrid development and use and whether microgrid operators that technically distribute energy to retail customers should be classified as public utilities and subject to regulations ordinarily imposed on such entities. California is currently exploring the potential benefits of microgrids and the role of state regulation.
New Jersey advanced several of the Murphy administration’s clean energy goals during June 2019. Over the past month, the state released a draft of its revised Energy Master Plan (EMP), approved the Ocean Wind offshore wind project proposed by Ørsted, and released a detailed analysis on energy storage development in New Jersey.
Consolidated Edison Company of New York, Inc. (Con Edison) and Orange and Rockland Utilities, Inc. (O&R) issued a draft joint Request for Proposals (RFP) on May 31 to competitively procure scheduling and dispatch rights from new energy storage projects. Through this initial solicitation, Con Edison and O&R are targeting at least 300 megawatts (MW) and 10 MW, respectively, of new energy storage facilities to meet the in-service deadline of December 31, 2022, set by the New York Public Service Commission (NYPSC) in its December 2018 Order (Storage Order) establishing New York’s three gigawatt (GW) energy storage deployment goal.
Both utilities will accept bids only for new storage projects sized over five MW and connected to the transmission or distribution system that can directly participate in New York Independent System Operator (NYISO) markets and provide distribution benefits, if applicable. These front-of-meter systems must be able to discharge for at least four hours 100 to 350 times per year, have at least 85% roundtrip efficiency, and maintain 98% availability for dispatch each contract year.
A recent grid reliability report issued by staff members of the Offices of Electric Reliability and Enforcement within FERC evaluating the upcoming operating season underscored the changing generation resource mix in the United States and its implications for grid operations.