EPCOR USA Inc., part of EPCOR Utilities Inc. (EPCOR), has signed a deal to divest its natural gas utility in Texas to SiEnergy Operating, a subsidiary of Northwest Natural Holding Co., for $60 million. Hughes Gas Resources Inc., or EPCOR Texas Gas, has about 6,900 metered connections and 353 miles of pipeline serving 12 communities northeast of Houston. “EPCOR Texas Gas, which has owned and operated the assets since 2017, is expected to have a rate base of approximately $46 million at the end of 2025”, a joint statement said. The parties expect to close the transaction this quarter. “With a similar business model as SiEnergy, Hughes has grown organically by providing infrastructure to residential and commercial developments in high-growth areas surrounding Houston”, commented Northwest Natural chief executive Justin Palfreyman. “EPCOR Texas Gas is a great fit for us as we continue to expand and diversify our overall utility portfolio in Texas”. EPCOR Utilities president John Elford said the sale is part of the company’s drive to focus on water opportunities in the state. “Our customers in Texas will benefit from SiEnergy’s substantial footprint in natural gas utilities while EPCOR continues to focus on growing its water business in the United States”, said Joe Gysel, EPCOR senior vice president for North American commercial services.  Besides SiEnergy, Northwest Natural also owns Northwest Natural Gas Co., which provides natural gas services to around 2 million people in over 140 communities through 800,000 meters in Oregon and Southwest Washington. Another Northwest Natural subsidiary, NW Natural Renewables Holdings, is investing in the production of low-carbon renewable natural gas from food, agricultural and forestry waste, landfills and wastewater. Meanwhile NW Natural Water Co. delivers water and wastewater utility services in Arizona, Idaho, Oregon, Texas and Washington. EPCOR USA provides water, wastewater, wholesale water and natural

The Panna-Multa and Tapti (PMT) joint venture partners, Shell PLC, Reliance Industries Limited (RIL), and Oil and Natural Gas Corporation Limited (ONGC), have completed India’s first offshore facilities decommissioning project. According to ONGC, the project entailed the removal of mid and south Tapti field facilities, which ceased production in March 2016. The PMT joint venture operates the Tapti fields under a production sharing contract with the Indian government. ONGC holds a 40 percent share, while RIL and BG Exploration & Production India Ltd (BGEPIL-Shell) each hold 30 percent. ONGC said the project also involved the removal of five wellhead platforms, associated infield pipelines, load-in at the onshore dismantling yard and the safe plugging and abandonment of 38 wells – all executed in line with the approved decommissioning plan. “The project’s complexity, especially its proximity to ONGC’s live assets, demanded strategic planning, precise execution, and utmost focus on safety. It marks a defining moment in India’s energy landscape and sets a strong foundation for the next chapter in offshore infrastructure transformation”, Pankaj Kumar, Production Director at ONGC, said. To support the government’s “Make in India” vision, the PMT JV awarded contracts to Indian firms Larsen and Toubro (L&T) for offshore work and Chowgule Shipyard (CLSPL) for onshore dismantling. Offshore operations have been completed, while dismantling is ongoing at CLSPL’s Ratnagiri facilities, ONGC said. The Tapti decommissioning project has also set a benchmark for India’s regulatory and operational framework for offshore decommissioning, developed in collaboration with key stakeholders like MoPNG, DGH, and OISD, following global best practices adapted for local conditions, ONGC said. “The safe and successful completion of the Tapti offshore project is a landmark moment for India’s offshore energy sector. This project sets a new benchmark for responsible decommissioning, made possible by global expertise, strong collaboration, and an unwavering commitment to

U.S. natural gas is trading higher today on a combination of technical factors and geopolitical tensions that pose the potential for supply disruptions. That’s what Art Hogan, Chief Market Strategist at B. Riley Wealth, told Rigzone in an exclusive interview on Wednesday when asked why the U.S. natural gas price is rising today. “Technically natgas is trading above key support of $3.47, which is the 50-day Exponential Moving Average (EMA),” Hogan said. “The next resistance sits at $3.72. On the fundamental side of things, the American Petroleum Institute data released yesterday reflected tighter supply,” he added. “Additionally, U.S. energy firms like Diamondback Energy and Coterra Energy have announced rig reductions, potentially curbing future output,” he continued. Rigzone has contacted Diamondback and Coterra for comment on Hogan’s statements. The companies have not responded to Rigzone at the time of writing. In its first quarter results statement, which was posted on the company’s website on May 5, Diamondback said it “is reducing its activity levels and lowering its capital budget to prioritize free cash generation”. In Coterra’s first quarter results statement, which was published on the company’s site on Monday, Tom Jorden, Chairman, CEO and President of Coterra, said, “we believe it is prudent to reduce oil directed activity at this time”. “As such, we are lowering Permian investment in 2025 and now expect to average seven Permian rigs during the second half of the year, down 30 percent from our original guidance of ten,” he added. “As planned, we added two natural gas focused rigs in the Marcellus in April and may keep this activity running for the balance of 2025,” he went on to state. When he was asked why the U.S. natural gas price is rising today in a separate exclusive interview, David Seduski, the head of North American

Dive Brief: The Environmental Protection Agency plans to end its popular Energy Star program, according to widespread media reports. The program has helped consumers identify energy-efficient home appliances for more than 30 years. The “next phase of organizational improvements” to the EPA was announced Friday, an agency spokesperson said in an email. A current and future organization chart of impacted offices was provided. Eliminating the Energy Star program will reduce consumer access to vital information about the energy use of appliances, efficiency advocates said. “If you wanted to raise families’ energy bills, getting rid of the ENERGY STAR label would be a pretty good way,” American Council for an Energy-Efficient Economy Executive Director Steven Nadel said in a statement. Dive Insight: Energy Star was created in 1992 under President George H.W. Bush and expanded over the years as its popularity grew. The program has helped consumers save more than $500 billion in energy costs and 5 trillion kWh since its inception, according to the program website. Energy Star has “grown to become the international standard for energy efficiency and one of the most successful voluntary U.S. government programs in history,” according to the EPA. The program “and all the other climate work, outside of what’s required by statute, is being de-prioritized and eliminated,” Paul Gunning, director of EPA’s Office of Atmospheric Protection, told employees on Monday, The New York Times reported. In April, more than 1,000 companies and organizations lobbied EPA to maintain the program, noting that “a typical household can save about $450 on energy costs each year” by choosing Energy Star products. The program has more than 16,000 participating companies and organizations, including over 1,800 manufacturers, who rely on the Energy Star program “to drive consumer demand for energy efficiency.” Energy Star-certified homes — those built to meet strict energy efficiency standards set

Matt Carrara is president of Doble Engineering. As the world transitions toward a more electrified and interconnected future, this will be a pivotal year for the power industry. With growing energy demands, the shift toward renewable energy and an aging workforce, utility professionals are at the forefront of solving some of the world’s most critical challenges. These trends underscore the need for bold thinking, teamwork and a relentless focus on resilience. Here are four key trends shaping the power industry this year and the strategies needed to navigate these challenges effectively. Workforce challenges: Bridging the talent gap The power industry is facing a workforce shortage as experienced professionals retire at an accelerated pace. According to the Department of Labor, nearly half of the current workforce in the sector will retire within the next decade. At the same time, non-retirement turnover has increased significantly, further compounding the talent gap. This loss of institutional knowledge coincides with a surge in electricity demand driven by electric vehicle adoption, data center expansion and renewable energy integration. The industry’s ability to attract, train and retain the next generation of workers is vital for maintaining grid reliability and enabling future innovation. To address these challenges, utilities must rethink talent acquisition and workforce development. Structured mentorship programs can facilitate knowledge transfer between retiring experts and younger professionals, preserving technical expertise and fostering leadership skills. Training programs must evolve beyond traditional methods to include digital literacy, adaptability, and proficiency in emerging technologies like AI and machine learning. Hands-on experience through advanced simulation environments can better prepare workers for modern grid management. Expanding recruitment efforts and supporting underrepresented groups will introduce fresh perspectives, enhancing industry resilience. Additionally, to compete for talent, utilities must offer competitive salaries, career growth opportunities and innovative work environments. Bringing in new talent isn’t just

The New Jersey Board of Public Utilities on Tuesday issued a request for information to explore whether new nuclear power plants could advance the state’s goals on electricity affordability, resource adequacy and clean energy. The RFI comes as modeling for New Jersey’s upcoming Energy Master Plan indicates New Jersey will need up to 10 GW of clean, firm capacity to maintain system reliability after 2035, partly in response to growing data center demand forecasts, the BPU said. New Jersey aims to have 100% clean electricity by 2035. “As we work to push PJM to improve their interconnection queue to allow more resources like solar and storage to be built in the short-term, expanding our nuclear fleet offers the Garden State an opportunity to add new generation to our resource mix, improving reliability and affordability for ratepayers in the long-term,” Christine Guhl-Sadovy, BPU president, said in a press release. New Jersey has three nuclear power reactors: the Salem 1 and 2 units, which total 2,285 MW, and the 1,172-MW Hope Creek unit. PSEG Power owns the Hope Creek plant and 57% of the Salem capacity. The rest of the Salem plant is owned by Constellation Energy. The reactors generate 40% of New Jersey’s electricity and account for 85% of the state’s emission-free generation, according to the BPU. In the RFI, BPU staff is seeking answers to a range of questions, including how nuclear electricity production can address the needs of large loads such as AI data centers and how ratepayers can be protected from the effects of using existing nuclear power plants for data centers. Agency staff also want to know whether New Jersey should provide financial assistance or incentives for new nuclear generating capacity and how incentive programs could be designed to support the state’s economy while protecting ratepayers. “What