Centalion Group, one of the largest commodity traders in the world formerly known as Gunvor, said Monday it has boosted its position in the Haynesville Shale and is now one of the play’s largest private operators as it continues to expand its US natural gas assets.

Abu Dhabi National Oil Co. (ADNOC) said its gas trading affiliate has agreed to supply Thailand’s Gulf Group with 2 Mt/y of LNG beginning in 2027.

Market participants took note of weakening weather demand, LNG strength and mixed reads on supply as natural gas futures treaded lightly in early trading on Tuesday.

Argentina’s state energy company YPF has narrowed the timeline for a final investment decision (FID) on its proposed Argentina LNG project to late November, as US financing and contractors deepen their exposure to the Vaca Muerta Shale.

November natural gas futures climbed Monday morning, rebounding from an early break below $3.00/MMBtu as a sharp decline in Lower 48 supply provided support despite a mild weather outlook.

Weekly natural gas cash prices fell as weather tilted in bears’ favor and total supply, while moderating, remained sturdy by autumn standards.

Key insights on the natural gas market provided by NGI's price and data analysts

Canada’s top natural gas producer Tourmaline has instituted a strategic “capital pause” on new midstream infrastructure development until regional AECO benchmark prices recover toward C$4.00/GJ.

Venture Global has filed a request with the Federal Energy Regulatory Commission to officially place its 3.6 Bcf/d Plaquemines LNG facility in service and begin commercial operations.

Natural gas futures teetered between positive and negative early Monday as traders wrestled with wavering weather demand, uneven production and a lingering but leaner storage surplus.

Spot natural gas prices fell broadly Friday as traders priced a three-day weekend package into mild early-October demand, though Southern California bucked the trend as pipeline constraints combined with lingering heat to support the region.

Natural gas futures clawed back the $3.00/MMBtu threshold Friday, with the prompt month reversing sharply from an early sell-off as pipeline uncertainty and approaching cooler weather provided support against a still-loose fundamental backdrop.

Aside from customary shoulder season doldrums, natural gas demand proved strong throughout the bulk of this decade, bolstered by weather extremes, economic growth, a Gulf Coast export expansion and, more recently, energy needs to fuel artificial intelligence (AI). The latter continues to prop up the economy, but that piece of the pie may be vulnerable.

ConocoPhillips is deepening its bet on US Gulf Coast LNG, signing a long-term supply deal with Venture Global that extends a recent run of 20-year-plus contracts for US export capacity.

NGI’s SoCal Border Avg. spot price climbed to $3.505/MMBtu Thursday, up 93.0 cents from Sept. 25, before El Paso Natural Gas (EPNG) declared a force majeure at its Seligman C compressor station (CS).

Natural gas stored in the South Central region closed out the final full week of September below the five-year average and far from year-earlier levels, despite record production in the Permian Basin.

The Western Canadian natural gas market is undergoing a major structural shift as new export capacity and domestic demand growth begin to reshape the basin’s supply and demand dynamics. Although a warm Pacific Northwest winter and temporary US West Coast dislocations have kept near-term AECO prices muted, the ramp-up of LNG Canada and an emerging wave of local industrial demand are laying the groundwork for a significantly tighter market. As producers navigate pipeline congestion and volatile regional basis, the long-term outlook hinges on balancing disciplined capital allocation against massive future energy needs. In this episode of NGI’s Hub & Flow podcast, NGI’s Christopher Lenton and Andrew Baker discuss shifting Canadian market dynamics with Canada’s biggest natural gas producer. Tourmaline Oil’s Vice President of Capital Markets Jamie Heard dissects what could drive AECO pricing higher, including the outlook for LNG Canada’s full operational impact and under-the-radar demand from both Alberta’s oilsands and behind-the-meter data centers.

Natural gas futures kicked off Friday’s session trading gingerly and, barring a shift in direction, the front month was headed for its fourth loss this week amid largely stagnant – and bearish – demand-side fundamentals.

Spot natural gas prices surged across the West Thursday, with sharp gains stretching from the San Juan Basin into Southern California amid pipeline constraints and heightened attention to supply reliability. Steep Northeast losses limited the nationwide advance.

Natural gas futures extended their losses Thursday as an in-line storage report failed to counter pressure from mild autumn weather and soft seasonal demand, leaving November below the $3.00/MMBtu mark.

Front-month natural gas futures struggled for meaningful momentum this week amid forecasts for increasingly mild weather. Contracts spanning December through February, the heart of winter, followed a similar pattern, though there were hints of a bullish hue as analysts cautioned that lighter production could leave the market vulnerable to weather surprises.

Transcontinental Gas Pipe Line (Transco) expects to start service Nov. 1 on two Texas expansions totaling 285,000 Dth/d, with one set to move Louisiana natural gas west into Houston for CenterPoint Energy and the other to serve a Vistra coal plant slated to switch to natural gas.

After the latest weekly government storage data aligned with consensus expectations, November natural gas futures remained rangebound on either side of $3.00/MMBtu as of midday Thursday.

The US Energy Information Administration (EIA) on Thursday reported an injection of 64 Bcf natural gas into storage for the week ended Sept. 25. The result exceeded expectations by just a hair and left New York Mercantile Exchange gas futures adrift.

The Western Canadian natural gas market is undergoing a major structural shift as new export capacity and domestic demand growth begin to reshape the basin’s supply and demand dynamics. Although a warm Pacific Northwest winter and temporary US West Coast dislocations have kept near-term AECO prices muted, the ramp-up of LNG Canada and an emerging wave of local industrial demand are laying the groundwork for a significantly tighter market. As producers navigate pipeline congestion and volatile regional basis, the long-term outlook hinges on balancing disciplined capital allocation against massive future energy needs. In this episode of NGI’s Hub & Flow podcast, NGI’s Christopher Lenton and Andrew Baker discuss shifting Canadian market dynamics with Canada’s biggest natural gas producer. Tourmaline Oil’s Vice President of Capital Markets Jamie Heard dissects what could drive AECO pricing higher, including the outlook for LNG Canada’s full operational impact and under-the-radar demand from both Alberta’s oilsands and behind-the-meter data centers.

Natural gas futures kicked off October trading today much in the way they closed out September – drifting in a range around $3.00, awaiting a fresh catalyst. The market could get that spark this morning, however, with the latest federal inventory print.

Physical natural gas prices finished mostly lower Wednesday as comfortable temperatures in the East sent Appalachia and Northeast hubs back toward $1/MMBtu, while lingering 90s across the Southeast produced some of the session’s most sizable gains.

Natural gas futures searched for direction Wednesday, dipping below $3.000/MMBtu before finishing modestly higher on the day as traders weighed thinning production against weak shoulder season demand ahead of Thursday’s government inventory report.

The recent diplomatic thaw between Venezuela and neighboring Trinidad and Tobago marks a critical turning point for regional energy integration, and could mean more LNG from the Americas reaches an energy-hungry global market.

Subdued production lent bullish support to natural gas futures on Wednesday, offset by a largely unsupportive two-week weather outlook. The November New York Mercantile Exchange (NYMEX) contract traded sideways as a result.

Natural gas spot prices in West Texas held firmly in positive territory through September as robust late-summer weather demand and elevated LNG feedgas consumption offset near-record Permian Basin production.

Daily natural gas prices in South Louisiana, home to national benchmark Henry Hub, are on average the highest in the country as the market nears the end of September.

Natural gas futures fought for traction early Wednesday after three sessions of losses, as traders took note of lighter production estimates and steady LNG volumes but also focused on bearish weather.

Western Canadian natural gas producers got a boost Tuesday from news that Shell had sanctioned the second phase of LNG Canada.

November natural gas futures slid in their first day as the prompt month Tuesday, pulled down by mild early October weather forecasts and restored Appalachian pipeline flows.

Cheniere Energy said Tuesday it signed its first long-term agreement with Brazil’s state-owned Petrobras LNG to sell the company the super-chilled fuel for more than 20 years.

Typically light shoulder season demand weighed on November natural gas futures in the contract’s first session at the front of the curve, although lower production and tightening storage balances versus historical norms offered a bullish counterweight.

November natural gas futures debuted as the prompt month on Tuesday under pressure, owing in part to fading demand, downward momentum following a two-day slump and a technical floor that crumbled.

Shell on Tuesday sanctioned the second phase of LNG Canada, which would double the facility’s capacity to 28 Mt/y and boost output at a time when roughly 20% of global supplies have been curbed indefinitely by the Iran war.

November natural gas futures searched for direction in morning action Tuesday as traders weighed bearish near-term weather against bullish production readings and a bright outlook for LNG volumes.

October natural gas futures eased Monday as restored Appalachian supply and fading shoulder season demand weighed on the front of the curve.

Last week marked not only the start of autumn, but also a return to more autumn-like weather in the Lower 48.

Asian and European natural gas prices were climbing again on Monday as hopes for a quick reopening of the Strait of Hormuz faded.

A bearish weather outlook offset downwardly trending production as natural gas traders squared their positions ahead of the futures contract rollover at today’s close.

Spot natural gas prices in the latest weekly period fell across much of the East, hampered in part by a major pipeline outage that stranded supply and pulled the national average lower.

Natural Gas Pipeline Company of America LLC (NGPL) is asking the Federal Energy Regulatory Commission (FERC) to approve a 550,000 Dth/d pipeline expansion in the Texas Panhandle that would ship natural gas to power a planned Google data center.

Natural gas futures slumped early Monday as traders took stock of storm fallout, resolution of a major pipeline outage, evolving demand drivers and impending front month contract rollover.

Cash prices for natural gas delivered over the weekend and Monday swung with the weather as a sharp regional divide in temperatures kept demand expectations in flux, while a developing nor’easter and a major pipeline outage added layers of uncertainty.

Boardwalk Pipelines has completed the federal permitting process for its Kosciusko Junction Pipeline Project.

US and global oil and natural gas firms are pouring into Venezuela as the country’s new commercial frameworks and bountiful resources attract international attention.