Clean Energy Injecting RNG from Dairy into Pipeline Grid
Clean Energy Fuels completed its latest renewable natural gas (RNG) production facility at Ash Grove Dairy in Lake Benton, Minnesota.
Now producing pipeline quality RNG and injecting it into the interstate natural gas pipeline grid, the facility is projected to supply up to 480,000 gasoline gallon equivalent of negative carbon-intensity RNG annually when at full capacity and will provide Clean Energy’s stations with clean-burning fuel for its commercial transportation fleet customers.
Located on a 55-acre site, Ash Grove Dairy is a multigenerational dairy farm home to more than 2,000 milking cows that produce milk, cheese, yoghurt and now clean RNG.
The freestanding one-digester facility will process up to 60,000 gallons of manure each day, capture its harmful methane and prevent it from entering the atmosphere. This biogas will be converted into an estimated 165 MMBtus of RNG every day.
The project, financed through one of Clean Energy’s production joint ventures and developed by Dynamic Renewables, totaled $22 million and has now passed necessary gas testing and is officially producing ready-to-use RNG. Clean Energy is in the process of filing the applications to generate federal and state environmental credits.
Blackcomb Pipeline Greenlit for Permian to Gulf Coast Flow
WhiteWater, MPLX LP, Enbridge and Targa Resources finalized plans for the Blackcomb Pipeline, a 365-mile natural gas pipeline from the Permian Basin to the Gulf Coast.
This decision follows the successful securing of firm transportation agreements with major shippers, including Devon Energy, Diamondback Energy, Marathon Petroleum, and Targa Resources.
The Blackcomb Pipeline will span 365 miles and have a capacity of up to 2.5 Bcf/d. It will connect gas production sites in the Permian Basin to the Agua Dulce area in South Texas, drawing from multiple upstream sources such as gas processing facilities in the Midland Basin and the Agua Blanca Pipeline.
“Blackcomb will provide much needed incremental natural gas takeaway capacity for Permian shippers,” said WhiteWater CEO Christer Rundlof.
The pipeline project, with WhiteWater managing construction and operations, is expected to be operational in the second half of 2026, pending regulatory approvals. The ownership structure of the Blackcomb Pipeline includes 70% by WPC, 17.5% by Targa, and 12.5% by MPLX.
In July, WhiteWater’s ADCC pipeline in South Texas began commercial service, enhancing natural gas transport amid rising U.S. LNG exports. The 40-mile pipeline, capable of moving about 1.7 Bcf/d, connects the Whistler Pipeline’s Agua Dulce Header to the Cheniere Corpus Christi Liquefaction facility. This development is crucial as the U.S. continues to lead global LNG exports, with a forecast of 12.2 Bcf/d this year.
The ADCC pipeline is jointly owned by Whistler Pipeline (70%), a collaboration between WhiteWater, MPLX, and Enbridge, and Cheniere (30%). It enables Cheniere to directly access natural gas volumes from the Permian and Eagle Ford regions, along with other sources along the Gulf Coast, supporting the U.S.’s dominant position in the global LNG market.
Spain Approves Section of H2MED Hydrogen Pipeline
The Spanish government gave the green light to gas grid operator Enagas on development of the Spanish section of a planned trans-European hydrogen pipeline and related hydrogen infrastructure projects.
Enagas, which is 5%-owned by Spain, is moving from its traditional role as a gas grid operator to managing a network of hydrogen infrastructure, taking advantage of the government’s plans to become a European hub for green hydrogen.
Key to the plan is the H2MED hydrogen pipeline project, which would connect the Iberian Peninsula to France, then moving into Central Europe by 2030. Enagas is teaming up with French, German and Portugal to develop the project. It expects net investment of around $3.5 billion (3.2 billion euros) through 2030 to develop its hydrogen projects, including the H2MED corridor.
McDermott Wins EPCI Contract for Offshore Gas Project
McDermott has been awarded an engineering, procurement, construction, installation (EPCI), hook up and commissioning contract by Shell Trinidad and Tobago Ltd. for the Manatee gas field development project, located 60 miles (100 km) off the southeast coast.
The award follows the successful delivery of the front-end engineering design, detailed engineering and long lead procurement service contracts for the project's initial design and execution planning.
Under the contract scope, McDermott will design, procure, fabricate, hook up and commission a platform and jacket. The company will also provide design, installation and commissioning services for a 32-inch gas pipeline that will connect the platform to a gas processing facility operated by Shell. The contract scope also includes design, procurement, installation, and testing services for a fiber optic cable.
“This award leverages our unique, integrated EPCI capabilities and legacy of engineering excellence and innovation to successfully deliver large offshore platforms and complex subsea infrastructure worldwide,” said Mahesh Swaminathan, McDermott's Senior Vice President, Subsea and Floating Facilities. “The Manatee project builds on our track record of successful project execution for Shell and exemplifies our commitment to building energy infrastructure required to meet demand.”
This contract award also demonstrates our continued commitment to working in Trinidad and Tobago to support the future supply of gas to its domestic and export market.
Golden Pass LNG Delay to Impact Global Markets During Growth
The six-month delay to the Golden Pass LNG Terminal LLC planned start-up in Texas will remove a fair amount of new supply from the market in a period of intense growth, shifting the surge from 2026 to 2027 and affecting both the global and North American gas markets, according to Wood Mackenzie.
“We have revised our forecast start-up for Golden Pass LNG by six months to December 2025,” said Mark Bononi, principal North America Gas and LNG Asset Research at Wood Mackenzie. “Specifically, we have pushed back first exports from Train 1 from June 2025 to December 2025. Similarly, we postponed first exports from Train 2 from December 2025 to June 2026, and Train 3 from June 2026 to December 2026 – keeping a six-month window between the start-up of the trains.”
According to Wood Mackenzie, this delay will remove 2.3 mtpa and 5.2 mtpa of growth from its forecast of supply in 2025 and 2026, respectively, equivalent to about 320 MMcf/d and 725 MMcf/d of feed gas in 2025 and 2026.
“A full year’s delay [from our previous view], which remains a risk, would result in a decrease of 10 mtpa in our global LNG supply forecast for 2026 and a reduction of 5 mtpa for 2027,” added Bononi. “Because of its size, Golden Pass LNG’s deferment could briefly impact global LNG prices and US natural gas production and prices. Depending on the project’s construction, there remains risks of further delays at Golden Pass LNG, and it could signal challenges to other U.S. LNG projects.” P&GJ