The combined count of crude oil, natural gas, and miscellaneous rigs in the US rose by 5 to 593 in the week ending Aug. 14, according to data from Baker Hughes (BKR) released Friday.
The US oil rig count increased by one from 454 the previous week to 455, while the number of gas rigs was up by four from 124 the previous week to 128, the data showed.
Price: $65.03, Change: $+1.59, Percent Change: +2.50%
US wholesale electricity markets were mixed Thursday afternoon, with New York Independent System Operator's intraday prices reaching as high as $261.07 per megawatt-hour, according to data from GridStatus.io.Electric Reliability Council of Texas' real-time locational marginal price was $23.13/MWh at 4 p.m. ET. Net load stood at 39.15 gigawatts, with solar accounting for the largest share of the generation mix at 36.3%.California Independent System Operator's real-time LMP was $16.84/MWh at 4 p.m. ET. Net load reached 3.06 GW, with solar accounting for the largest share of the generation mix at 56%.Southwest Power Pool's real-time LMP was $42.22/MWh at 4 p.m. ET. Net load stood at 41.79 GW, with natural gas accounting for the largest share of the generation mix at 36%. Prices climbed to an intraday high of $235.39/MWh at 3:10 p.m. ET.PJM Interconnection's real-time LMP was $81.21/MWh at 4 p.m. ET. Net load reached 121.63 GW, with gas accounting for the largest share of the generation mix at 43%. Prices reached an intraday peak of $259.92/MWh at 3:40 p.m. ET.Midcontinent Independent System Operator's real-time LMP was $61.74/MWh at 4 p.m. ET. Net load stood at 93.82 GW, with natural gas accounting for the largest share of the generation mix at 36.9%. Prices surged to an intraday high of $196.51/MWh at 4:40 p.m. ET.NYISO's real-time LMP was $53.54/MWh at 4 p.m. ET. Net load reached 23.04 GW, with dual-fuel accounting for the largest share of the generation mix at 35.8%. Prices peaked at $261.07/MWh at 3:45 p.m. ET.ISO New England's real-time LMP was $95.82/MWh at 4 p.m. ET. Net load stood at 16.02 GW, with natural gas accounting for the largest share of the generation mix at 51.1%.Independent Electricity System Operator's real-time LMP was $69.25/MWh at 4 p.m. ET. Net load stood at 20.97 GW, with nuclear accounting for the largest share of the generation mix at 40.8% at 3:55 p.m. ET.The National Weather Service's Climate Prediction Center forecasts temperatures to stay above normal across most of the country from Aug. 21-27.
US natural gas futures extended losses in after-hours trading Thursday after government data showed a larger-than-expected increase in underground storage, adding to pressure from strong production and above-average inventories.The front-month Henry Hub contract and the continuous contract were both down 2.57% at $2.732 per million British thermal units.Thursday's selloff accelerated after the US Energy Information Administration reported that natural gas inventories increased by 36 billion cubic feet in the week ended Aug. 7. The build exceeded analysts' expectations for a 31 Bcf increase and the five-year average build of 33 Bcf.Working gas in underground storage totaled 3,153 Bcf, the EIA said, leaving inventories 25 Bcf below year-earlier levels but 198 Bcf above the five-year average of 2,955 Bcf. US nat-gas inventories are currently 6.7% above their 5-year seasonal average, a sign of robust supplies, Barchart said.Storage growth has now exceeded the seasonal benchmark for four consecutive weeks and seven of the past eight weeks, widening the surplus to the five-year average, the Energy Buyers' Guide said.Lingering heat across Texas and the Southeast continues to bolster power-sector demand, providing some underlying support for gas prices. But strong production and healthy inventories are increasingly weighing on the market as peak summer demand begins to fade.US natural gas production is averaging a record 111.2 Bcf/d so far in August, up from 110.7 Bcf/d in June, according to Trading Economics.Supply remains more than sufficient to meet power-sector demand of 48.9 Bcf/d and LNG feedgas demand of 18.2 Bcf/d, Gelber & Associates said.Near-term heat is expected to keep power demand firm, while LNG feedgas demand is forecast to rise to 19.9-20.3 Bcf/d over the next two weeks as export facilities ramp up.
Alaska Governor Mike Dunleavy said Thursday he was "deeply disappointed" by lawmakers' decision to delay action on a property tax change needed to advance the state's natural gas pipeline project, warning of higher risks and costs.In a post on X, Dunleavy said, "Alaska is running out of affordable, reliable natural gas," calling the shortage a long-standing issue that has grown more urgent after decades of inaction.The governor said delaying the proposed measure could affect households and major institutions across the state, including military installations, schools, hospitals, universities and businesses that depend on reliable and affordable energy."Reliable, affordable energy is essential to Alaska's economic stability and quality of life," Dunleavy said, adding that a delay "increases risk, raises costs, and limits future options."Dunleavy also warned that the legislature's decision could weaken investor confidence in Alaska, the US and overseas, as large infrastructure projects require certainty and sustained commitment."We will continue to pursue all viable options to advance the Alaska natural gas pipeline project," Dunleavy said, describing reliable and affordable energy as both an economic necessity and a responsibility to current and future generations.Alaska LNG project aims to expand access to gas for domestic use while supporting LNG exports to Asia. Japan's JERA and Tokyo Gas have signed preliminary agreements to buy a combined 2 million metric tons per year, while the project targets 20 million metric tons per year in exports, according to a Reuters report.Lawmakers are being urged by Dunleavy to reconvene Aug. 20 to vote on the proposed measure, the report added citing KTUU.The White House and the US Department of Energy did not immediately reply to' request for comment.