The Norwegian Offshore Directorate granted Aker BP a drilling permit Thursday for wellbore 36/4-2 in production license 1153 in the North Sea.
The approval, issued under Section 13 of the Resource Management Regulations, clears Aker BP to proceed with drilling activities.
Aker BP holds a 40% operating stake in production license 1153, while Inpex Idemitsu Norge owns 30%, Okea holds 20%, and Harbour Energy Norge controls the remaining 10%, according to the Directorate.
Clean Energy Fuels (CLNE) secured two contracts in Puerto Rico to support 10 megawatts of installed power capacity through liquefied natural gas infrastructure projects, the company said Tuesday.The agreements mark Clean Energy's first LNG supply infrastructure projects in Puerto Rico and expand the company's energy services business beyond its traditional transportation fuel market.One contract covers LNG station equipment and installation for a global healthcare products supplier, which selected natural gas infrastructure to support reliable power for its pharmaceutical manufacturing operations.Separately, Clean Energy signed an agreement with PR Energy Partners to design and construct an LNG supply station to serve a 6 MW combined heat and power plant that supports residential and hotel properties in Puerto Rico.The company said the two projects will provide energy security and resiliency for both customers' operations in Puerto Rico."Being chosen as the trusted partners and experts in natural gas and LNG supply systems is a confirmation of our expansion into different energy services," Sean Columbia, general manager of CE Technologies at Clean Energy, said."These projects demonstrate the reliability and scalability of our engineered LNG solutions and will help strengthen energy resilience on the island," Columbia added.Clean Energy said its modular LNG infrastructure can provide primary and backup power for applications including manufacturing facilities, hospitals, data centers, ports, industrial sites and power generation projects, while offering lower emissions than diesel and fuel oil.
US natural gas markets are weighing the potential impact of Tropical Storm Arthur on Gulf Coast LNG exports, while cooler-than-expected weather and a sizable storage build are adding downward pressure on prices.The front-month Henry Hub contract and the continuous contract fell by 2.50% to $3.158 per million British thermal units.Tropical Storm Arthur, the first named storm of the Atlantic hurricane season, is expected to bring heavy rainfall to portions of the US Gulf Coast on Wednesday, including areas that host major LNG export facilities, multiple news outlets reported. According to the National Hurricane Center, the storm was located west-southwest of Lake Charles, Louisiana, on Wednesday afternoon and was moving northeast.While forecasters do not expect Arthur to strengthen significantly, the storm is expected to bring dangerous flash flooding across parts of the Gulf Coast. The National Hurricane Center said rainfall totals of 5 to 10 inches (12.7 to 25.4 centimeters) are expected through early Friday, with isolated areas potentially receiving up to 20 inches.Any disruption to liquefaction facilities could temporarily reduce overseas shipments of US natural gas, leaving more supply available in the domestic market and weighing on prices.Longer-term weather forecasts are also contributing to bearish sentiment. Commodity Weather Group said forecasts have shifted toward cooler conditions, with below-average temperatures expected across much of the Midwest through June 26, potentially reducing demand for electricity used for air conditioning.Meanwhile, traders are preparing for another strong weekly storage injection. The US Energy Information Administration's storage report, due Thursday, is expected to show an increase of roughly 80 billion cubic feet for the week ended June 12, according to market estimates. That would exceed the five-year average build of 73 Bcf for the period.A Wall Street Journal survey projected an average storage increase of 82 Bcf, with analyst estimates ranging from 66 Bcf to 117 Bcf, the Energy Buyers Guide said Wednesday. A build near consensus levels would expand the surplus of natural gas inventories relative to the five-year average to about 160 Bcf, up from 151 Bcf the previous week. However, inventories would remain roughly 20 Bcf below year-ago levels, compared with a deficit of 5 Bcf a week earlier, it said.Market data also pointed to ample supply. BNEF estimates, cited by Barchart, show US dry gas production at 110.1 Bcf/d on Wednesday, up 2.2% from a year earlier.Domestic gas demand was estimated at 69.4 Bcf/d, down 5.9% from the same period last year. Power sector demand softened as well. Celsius Energy estimated natural gas consumption by power generators at 23.2 Bcf late Wednesday, down 1.2 Bcf from the previous day and 2.3 Bcf below year-earlier levels.LNG demand remained strong despite storm concerns. BNEF estimated net gas flows to US LNG export terminals at 19.5 Bcf/d on Wednesday, up 12.9% from the previous week.
PJM's current capacity market structure does not provide sufficient economics to support new gas-fired generation at today's construction costs, Enverus said Wednesday.Enverus Intelligence Research, or EIR, said capital costs for new combined-cycle gas turbine projects have increased sharply from about $1,000 per kilowatt before 2024 to between $2,000/kW and $3,000/kW today.At current construction costs, merchant gas projects in PJM struggle to generate double-digit returns. EIR said returns drop below 10% once capital spending reaches $2,000/kW, while debt coverage metrics also come under pressure.Long-duration bilateral agreements could help finance some new projects, particularly where development costs remain near $2,000/kW, according to EIR.Even with capacity prices held at PJM's current market cap during the first 15 years of operation, developers face financing challenges when project costs rise to $2,500/kW or more, the report found.EIR's sensitivity analysis showed a plant costing $2,500/kW would require capacity prices of roughly $500/MW-day to reach commercially viable financing levels, well above PJM's existing cap of $333.44/MW-day."PJM needs new dispatchable capacity, but the economics of building it have moved faster than the market design," Principal Analyst Scott Wilmot said. "Bilateral contracts and capacity-market parameters will need to reflect the true cost of new entry, or developers may continue to favor existing assets over greenfield projects."