By the numbers: Consolidated Edison Q3 2025 -1.5% Consolidated Edison Co. of New York sold 15,692 million kWh in the third quarter of 2025, down slightly from 15,923 million kWh in the same period of 2024. After adjusting for weather and other variations, the utility said delivery volumes increased 0.3%. +10.6% CECONY’s sales of electricity reached $3.73 billion in the third quarter of 2025, up from $3.38 billion in the same period last year. $688 million Utility holding company Consolidated Edison saw its third quarter net income reach $688 million compared with $588 million in the same period of 2024. Rate case drives revenues Consolidated Edison Co. of New York, the electric utility serving New York City, warned customers heading into the summer that their bills would be going up. Now those sales are showing up on the utility parent company’s bottom line. Parent company Consolidated Edison also owns Orange and Rockland Utilities and Rockland Electric Co., as well as transmission and clean energy development businesses. “Third quarter 2025 results reflect [an] increase in electric rate base at CECONY,” the full name of the New York City distribution utility, the company said in its third quarter earnings presentation. Residential sales were flat but third quarter electric sale revenues at CECONY rose more than 5%, year over year. Commercial sales rose 3% and revenues jumped 13.9%. Retrieved from Consolidated Edison. And the utility has proposed spending almost $17 billion in New York City and Westchester County to build out its gas and electric systems from 2026 to 2028. Electric system spending is about $12 billion of the total.  If regulators approve, the spending plan “will fund critical infrastructure investments while keeping affordability and reliability front and center,” Chairman and CEO Tim Cawley said in a statement. “At the same time, the settlement

In an EBW Analytics Group report sent to Rigzone by the EBW team on Monday, Eli Rubin, an energy analyst at the company, noted that the December natural gas contract “pulled back to $4.268 [per million British thermal units (MMBtu)] intraday Friday before skyrocketing to test $4.509 [per MMBtu] this morning”. Rubin highlighted in the report that “a cold spell lifted weekend Henry Hub prices to a seven-month high of $3.76 [per MMBtu], LNG exports pushed a step-change higher to a record 18.1 Bcf/d [billion cubic feet per day], and weekend weather forecasts added eight HDDs [heating degree days] since Friday”. The EBW energy analyst went on to note in the report, however, that gas production set a record high on Sunday as Marcellus producers raised output into the first cold spell of the season. “Further, current cold weather may end mid-week, with daily weather-driven demand to slide 12.7 Bcf/d by Thursday,” Rubin added. “U.S. natural gas storage may reach Thanksgiving only slightly below 3,900 Bcf [billion cubic feet],” Rubin continued. Rubin went on to warn in the report that technical momentum may fizzle after having achieved the $4.50 per MMBtu target. “Chances for a cold December lie beyond the 1-15 day forecast window,” Rubin pointed out. “While another test of support is probable within the next 7-10 days, the bullish long-term structural outlook has limited both the duration and magnitude of any pullbacks – and may continue to offer support,” he added. In an exclusive interview with Rigzone on Monday morning, Art Hogan, Chief Market Strategist at B. Riley Wealth, said the fundamental backdrop continues to move natural gas prices higher. “Futures rose nearly three percent to around $4.45 per MMBtu, the highest since March and close to levels last seen in December 2022, lifted by strong export demand

EOG Resources Inc has consummated its takeover of Encino Acquisition Partners (EAP) from the Canada Pension Plan (CPP) Investment Board and Encino Energy for $5.7 billion subject to post-closing adjustments. “In the Utica, the integration of the Encino assets is proceeding exceptionally well, with continued incremental efficiency gains”, EOG chair and chief executive Ezra Yacob said in the company’s quarterly report. The transaction involved the purchase of CPP’s 98 percent stake and Encino Energy’s two percent stake in EAP, which the two formed 2017, CPP said May 30 announcing the deal. The acquisition grows EOG’s Utica shale position by 675,000 net acres to 1.1 million net acres with over two billion net barrels of oil equivalent undeveloped resources, Houston, Texas-based EOG said in a separate statement May 30. “Pro forma production totals 275,000 barrels of oil equivalent per day creating a leading producer in the Utica shale play”, EOG said then. “The acquisition expands EOG’s core acreage in the volatile oil window, which averages 65 percent liquids production, by 235,000 net acres for a combined contiguous position of 485,000 net acres”, EOG said at the time. “In the natural gas window, the acquisition adds 330,000 net acres along with existing natural gas production with firm transportation exposed to premium end markets. “In the northern acreage, where the company has delivered outstanding well results, EOG increases its existing average working interest by more than 20 percent”. EOG raised its regular dividend by five percent to $1.02 per share in light of the transaction. “EOG expects to generate more than $150 million of synergies in the first year driven by lower capital, operating and debt financing costs”, the May statement said. Yacob said then, “This acquisition combines large, premier acreage positions in the Utica, creating a third foundational play for EOG alongside our Delaware Basin and Eagle Ford assets”. The acquisition

Year to date through November 4, global oil demand growth is tracking an expansion of 0.85 million barrels per day. That’s what J.P. Morgan analysts said in a report sent to Rigzone by the JPM Commodities research team recently, adding that the expansion figure is 50,000 barrels per day below the company’s estimate of 0.90 million barrels per day. Global oil demand averaged 105.8 million barrels per day in October, the analysts noted in the report, pointing out that demand “consistently trail[ed]…” their estimates by 50,000 barrels per day throughout the month. The analysts said in the report that, for the first four days of November, they estimate global demand averaged 105 million barrels per day. They noted that this was an increase of 450,000 barrels per day compared with the same period last year but 30,000 barrels per day below their forecast monthly growth of 480,000 barrels per day. “High-frequency indicators suggest that U.S. oil consumption remains subdued, with travel activity declining as daily flights dropped seven percent week over week for the period ending November 3, largely due to the ongoing shutdown,” the analysts said in the report. “Additionally, U.S. container arrivals for November point to an eight percent decrease relative to last year, marking the third consecutive month of annual decline,” they added. “In East Asia, petrochemical feedstock demand continues to be softer than usual, while industrial activity in Germany has extended its downturn into a third consecutive month,” they continued. The analysts also stated in the report, which was sent to Rigzone on November 5, that global total liquids stocks “rose by 29 million barrels last week, bringing the year to date increase to 385 million barrels”. “Regionally, OECD liquid stocks have grown by 83 million barrels, while stocks in China have increased by 88 million

From redundancy to resilience: The next level of network diversity Despite billions invested in grid modernization and widespread adoption of dual-carrier approaches, many utilities still find their communications infrastructure vulnerable to disruption. It’s a paradox: utilities have engineered redundancy across power generation and distribution, yet communications—the digital backbone of the modern grid—often lacks the comprehensive diversity needed to truly eliminate single points of failure.  True grid resilience now depends on comprehensive network diversity that enables consistent quality of service, operational flexibility and long-term adaptability. The cost of connectivity blind spots As utilities expand advanced metering infrastructure (AMI), SCADA systems, distributed energy resource (DER) management and connected field operations, the strain on communications networks continues to grow. Relying on a single technology exposes utilities to significant risk—from natural disasters and carrier outages to rural coverage gaps and network congestion. The result: delayed outage restoration, compromised grid visibility and operational inefficiencies that undermine reliability and customer trust. The versatility imperative: Why utilities can’t just “upgrade” Utility communications can’t follow the consumer tech cycle. Equipment often remains in service for 20 to 30 years, even as wireless standards evolve from private radio networks to LTE, 4G, 5G and emerging spectrum such as Anterix Band 106. Each shift brings new performance expectations—but utilities can’t afford to rip and replace infrastructure every few years. Instead, they need adaptable, field-proven solutions that bridge technologies and spectrum generations, ensuring consistent, secure connectivity today while accommodating tomorrow’s innovations without interrupting critical operations. Three pillars of network diversity While many utilities have already adopted dual-carrier strategies, the expanding complexity of modern grid operations demands a renewed look at comprehensive network diversity. True resilience comes from a multi-path approach—one that enables seamless communication under any condition. Three key strategies define this new standard of reliability. A. Public-to-public redundancy Dual-radio routers

As utilities work to strengthen and modernize America’s electric grid, they face growing mechanical and environmental challenges below and between the lines. Buried grounding networks, pole grounds and substation grids must all withstand decades of stress from soil movement, moisture, corrosion and fault current events. Each of these physical forces can compromise a system’s electrical integrity — making mechanical strength as vital as electrical performance in ensuring long-term reliability. In earlier decades, utility conductors were relatively short, stationary and installed in stable soil. Today’s infrastructure is different. Expansion into remote terrain, widespread undergrounding and the integration of renewable and distributed resources have multiplied the number of grounding paths and exposed more cable to movement, vibration and stress. These systems must remain reliable through decades of shifting soils, thermal cycling and fault events — all while supporting uninterrupted power delivery. When a grounding conductor fails, the results can be costly. Broken bonds or weakened terminations can increase ground resistance, trigger equipment faults or leave assets unprotected from lightning and surge events. Repairs often require excavation, downtime and new material — expenses that compound across large service territories. In short, mechanical failure doesn’t just compromise safety; it undermines reliability, budgets and public confidence. That’s why conductor strength has become a defining factor in grid resilience. Copper-Clad Steel (CCS) conductors are engineered to meet this demand. By metallurgically bonding a copper layer to a high-tensile-strength steel core, CCS combines the conductivity of copper with the durability of steel. The result is a grounding conductor that resists stretching, breakage and deformation while maintaining long-term electrical integrity. Unlike soft copper, which can elongate or fracture under mechanical strain, CCS retains its shape and strength even after repeated mechanical or thermal stress. That strength translates into reliability you can measure. Stronger conductors stay tight at terminations, maintain