FERC Issues Final EIS for the Magnolia LNG Production Capacity Amendment Project

FERC Issues Final EIS for the Magnolia LNG Production Capacity Amendment Project

The Federal Energy Regulatory Commission (FERC or Commission) issued its Final Environmental Impact Statement (EIS) for the “Magnolia LNG Production Capacity Amendment proposed by Magnolia LNG, LLC (Magnolia LNG).” Magnolia LNG had request authorization to “increase the liquefied natural gas (LNG) production capacity of the previously authorized Magnolia LNG Project in Calcasieu Parish, Louisiana… from 8 million metric tonnes per annum (MTPA) to 8.8 MTPA. The increased production capacity would be achieved through the optimization of Magnolia LNG’s final design, including additional and modified process equipment.”

“The equipment changes identified by Magnolia LNG in its application and supplements and/or determined by FERC staff via data requests include the following:

·         “increased ammonia compressor capacity and system pressures;

·         “increased number of ammonia air coolers;

·         “increased mixed refrigerant system operating pressure;

·         “additional ammonia/mixed refrigerant cooler;

·         “additional heavy hydrocarbon removal vessels and compressor;

·         “relocation of main flare stack; and

·         “addition of marine flare stack.”

FERC noted that the EIS was prepared following the “requirements of the National Environmental Policy Act (NEPA), the Council on Environmental Quality regulations for implementing NEPA in 40 Code of Federal Regulations, Parts 1500–1508 (40 CFR 1500-1508), and FERC regulations implementing NEPA (18 CFR 380).” FERC stated that the “U.S. Department of Energy, U.S. Coast Guard, and U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration (USDOT PHMSA)” all aided in the preparation of the EIS.

FERC believes that “With the incorporation of the mitigation measures identified in the supplemental EIS, staff concludes the LNG terminal design would include acceptable layers of protection or safeguards that would reduce the risk of potentially hazardous scenarios from developing into an event that could impact the offsite public. USDOT PHMSA will issue a Letter of Determination regarding the facilities’ compliance with siting requirements for LNG facilities in 49 CFR 193 Subpart B.” The new facility would also “be subject to the USDOT PHMSA’s inspection and enforcement program.”

“FERC staff concludes that the modifications associated with the Production Capacity Amendment, with the additional mitigation measures recommended in the supplemental EIS, would continue to avoid or reduce impacts to less than significant levels.”

FERC Accepts NERC Performance Assessment, Bolsters Grid Reliability

FERC Accepts NERC Performance Assessment, Bolsters Grid Reliability

The Federal Energy Regulatory Commission (FERC) took action to ensure that the nation’s bulk power system remains secure and reliable by “approving two reliability standards and endorsing the continued work of the North American Electric Reliability Corporation (NERC).”

It was the Five-Year Performance Assessment for NERC, and FERC recognized that NERC has been developing and enforcing reliability standards and that it “continues to satisfy the criteria for certification as the [Electric Reliability Organization (ERO)] that is responsible for developing and enforcing the Commission’s mandatory reliability standards” and that the regional entities of NERC continue meeting their requirements as well.

NERC and the Regional Entities have made significant achievements over the last five years, including a risk-based approach to focus resources on matters of most significance to reliability,” FERC Chairman Neil Chatterjee said.

FERC found some areas of improvement for NERC: “the ERO’s periodic audits of the Regional Entities, its use of reliability and security guidelines to address risks, performance metrics and oversight of the Electricity Information Sharing and Analysis Center, sanctions guidelines and its organization certification program.”

NERC was also directed to “amend its Sanction Guidelines to provide more transparency into how it applies penalties, adjustment factors and non-monetary sanctions.” NERC must also submit ” any tools or formulas used to implement the guidelines” to FERC for review.

FERC also “approved reliability standards for Transmission System Planning Performance Requirements… and Cyber Security — Communications between Control Centers.” A Notice of Proposed Rulemaking was issued by FERC “that would approve NERC’s proposed retirement of 74 of the 77 Reliability Standards developed under NERC’s Standards Efficiency Review Project, which identifies standards that provide little benefit, are administrative in nature, or are redundant.”

The standards build on the “current standard by requiring a more comprehensive study of the potential impacts of protection system single points of failure. It also sets new requirements related to planned maintenance outages and stability analysis for spare equipment strategies.”

The new cyber standard will enhance the “current Critical Infrastructure Protection (CIP) standards on mitigating risks associated with communications between bulk electric system control centers. It requires responsible entities to protect the confidentiality and integrity of real-time assessment and real-time monitoring data transmitted between control centers.” NERC has also been directed to develop more “modifications requiring protections regarding the availability of communication links and data communicated between those control centers.”

Both of these new rules will go into effect 60 days after their publication in the Federal Register.

For more information on these rules and the NERC performance assessment, you can view them at:

Order E-20

Order E-21

Order E-22

Order E-24


FERC Issues Energy Infrastructure Update for November 2019

FERC Issues Energy Infrastructure Update for November 2019

The Federal Energy Regulatory Commission (FERC) issued its regular Energy Infrastructure Update for November 2019. This update covers the news and highlights for energy around the country, in gas, hydropower, and electric generation.

In November, one new natural gas pipeline was placed into service, bringing the year’s total up to 10, compared to 21 in 2018. Two pipelines were certified in November, bringing the year’s total up to 30, compared to 46 in 2018. There was nothing new for storage facilities in November. Two new LNG export facilities were placed into service, and another four import/exports were certified, bringing the year’s totals up to seven and 11, respectively; in 2018, there was only one of each.

There were no hydropower project activities in the month of November.

The electric generation highlights detailed the new and expanded units in November, along with year-to-date totals, and a comparison of this period in 2018. There was relatively little in this area in November. Only one new wind power unit was placed in service, which brings the total for the year up to 35, compared to 47 in 2018. Solar power had 13 units added, bringing the year’s total up to 364, compared to 514 in 2018.

There were a number of proposed additions and retirements of generation units in November, all planned to occur by November 2022. Coal had one proposed addition and 50 retirements. Natural gas had 213 additions, 98 of which are currently under construction, and 76 retirements. Nuclear power had seven additions, two are under construction, and six retirements. Oil had 11 additions, one is under construction, and 15 retirements. Hydropower had 241 additions, 95 are under construction, and 12 retirements. Wind power had 512 additions, 184 are under construction, and three retirements. Biomass had 51 additions, 21 are under construction, and 28 retirements. Geothermal steam had 12 proposed additions, four are in construction now, and no retirements. Solar power had the most proposed additions at 2,732, with 673 under construction; there were no proposed retirements for solar power.

For electric transmissions, in the ≤230 voltage range, six miles of line completed in November, compared to 49.7 the previous year. This brings the total for the year up to 190.6 miles, compared to 521.5 in 2018. There are another 533.8 miles planned to be added by December 2021. There was nothing new in the 345-voltage range or the 500-voltage range in November. There are a planned 637.5 miles for the 345-voltage, and 670 for the 500-voltage range.

FERC Approves Eastern Shore Natural Gas Company Expansion

FERC Approves Eastern Shore Natural Gas Company Expansion

On January 7, 2020, the Federal Energy Regulatory Commission (FERC) approved the Del-Mar Energy Pathway Project. In both, Kent and Sussex counties in Delaware, and Wicomico and Somerset counties in Maryland, it “approves the construction and operation of new infrastructure facilities.”

Chesapeake Utilities Corporation’s Senior Vice President, Jeff Sylvester, assures, “bringing natural gas to a new area results in many positive enhancements for the community, both environmental and economic.” The project could lead to an increase in job growth and overall service expansion.

The Regional Economic Studies Institute of Towson University concluded the project would economically benefit the region through direct, in-direct, and induced employment. The FERC’s approval meets a growing demand for natural gas services for the consumer, and furthermore “expands our partnership in the local communities in which we live and work, bringing natural gas service to Somerset County for the first time and providing a cleaner, reliable and more cost-effective energy choice for customers on the Delmarva Peninsula,” according to Jeff Tietbohl, the Vice President of Eastern Shore Natural Gas Company.

The construction of the Del-Mar Energy Pathway Project is set to begin within the first quarter of 2020. It will construct approximately 12 miles of natural gas infrastructure through Kent and Sussex counties and 7 miles through Wicomico and Somerset counties. Once running, it will provide roughly “11.8 million cubic feet per day of additional natural gas firm transportation service and 2.5 million cubic feet of off-peak transportation service to Chesapeake Utilities’ natural gas distribution subsidiaries on the Delmarva Peninsula and one industrial customer.”

The project is projected to cost approximately $37 million and reach completion within the fourth quarter of 2021. The foreseen annual gross margin for the Del-Mar Energy Pathway Project is $5.1 million.

For more information on the project, visit http://info.esng.com/delmar