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In December 2023, the U.S. set a new record by exporting 8.6 million tonnes of LNG. This spike was primarily fueled by two developments: the full return of Freeport LNG, which contributed an additional 6 million tonnes, and an increased output from Venture Global LNG’s Calcasieu Pass facility, adding 3 million tonnes over the previous year. 

Europe remained the main destination for U.S. LNG, receiving 61% of the exports in December, but this decreased from 68% in November. Asia also increased its imports significantly, taking in 26.6% of the exports, up from 18.5% in November. Latin America accounted for 6% of the exports.

The total regasification capacity reached 7,652 billion cubic feet in the broader North American context in 2022. 

When Cheniere Energy first built its regasification plant on the Gulf of Mexico, the United States was a major importer of natural gas. However, the rise in natural gas production from the country's shale formations dramatically shifted the market dynamics. Cheniere, in partnership with Bechtel, initially constructed and then expanded the Sabine Pass LNG receiving terminal from 2005 to 2009. 

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In 2016, they upgraded the facility to include liquefaction capabilities, allowing it to use existing storage tanks, berths, and pipelines for LNG exports. By September 2022, Sabine Pass Liquefaction became the first terminal in the world capable of handling three LNG tankers at the same time. 

Latest US LNG news

  • Texas is "an energy El Dorado" 

TotalEnergies of France recently bought a 20% interest from Texas-based Lewis Energy Group in the Dorado gas leases, operated by EOG Resources. EOG holds the remaining 80% stake. 

Located in the Eagle Ford shale gas field, this deal will increase TotalEnergies' U.S. natural gas production by 50 million cubic feet per day starting in 2024, with the potential to add another 50 million cubic feet per day by 2028. In 2023, TotalEnergies already produced around 340 million cubic feet per day, making it the top exporter of U.S.-origin LNG. It shipped over 10 million tonnes from its share in Louisiana's Cameron LNG facility.

  • Venture Global still spending $4 billion on CP2 

Venture Global is pushing forward with a significant $4 billion investment in its Calcasieu Pass 2 (CP2) LNG export terminal, slated for 2024. This project, along with 11 others, was affected by a U.S. pause on new LNG export approvals due to environmental concerns. However, the company remains committed to expanding its operations.

  • Texas LNG raises the stakes 

Glenfarne Group’s Texas LNG project has increased its preliminary LNG deal with U.S. player EQT Corporation by 1.5 million tonnes per annum (tpa), bringing the proposed total to 2 million tpa over the next 20 years. With this expansion, Texas LNG has secured nearly all the capacity for its planned 4 million tpa output. The facility, set to be constructed at the Port of Brownsville in Texas, is one of two projects by Glenfarne, with the other being the 8.8 million tpa Magnolia LNG facility planned for Lake Charles, Louisiana.

Top 10 active LNG in the US

  1. Sabine Pass Import LNG 

As of 2024, Sabine Pass stands as the largest operational export terminal for LNG in the United States, boasting an annual nameplate capacity of approximately 29.5 million metric tons.

Some key features of the operating facility:

  • Six trains with a total capacity of roughly 30 million tonnes per annum.
  • Five storage tanks, each with a capacity to hold 3.4 billion cubic feet of LNG.
  • Three LNG tanker berths.

The Sabine Pass Import regasification terminal, located in Louisiana, USA, is owned by Cheniere Energy and operated by Sabine Pass LNG. It began operations in 2008 with an LNG regasification capacity of 1,460 Bcf. It also ranks as the largest operational LNG terminal by capacity globally. 

Located on over 1,000 acres, the facility includes six liquefaction units, commonly referred to as trains, which collectively have a capacity of about 30 million tonnes per annum. The terminal's development has progressed steadily: the first two LNG trains were completed in 2016, trains 3 and 4 in 2017, train 5 in 2019, and most recently, the sixth train and a third berth were finished in 2022, both ahead of schedule and within budget.

Cheniere Energy has plans to further expand the terminal's capacity by an additional 20 million metric tons, reinforcing Sabine Pass's significant role in the global LNG market.

Corpus Christi

As of 2024, the facility maintains an annual nameplate capacity of 15 million metric tons. 

Corpus Christi, located in South Texas, is Cheniere Energy’s second LNG facility and the first greenfield LNG export facility in the continental United States. It started operations in 2018 and includes three liquefaction units, providing a total production capacity of 15 million metric tons per annum (mtpa).

In the first nine months of 2023, Cheniere Energy, as the nation's leading exporter, shipped 1,6784 trillion British Thermal Units (TBtu) from both the Sabine Pass terminal in Louisiana and the Corpus Christi facility in Texas. Both locations are currently undergoing expansions to further enhance their output capacities. 

Additionally, Cheniere is in the process of constructing five liquefaction trains at the Sabine Pass facility, which is a $20 billion project, and two at the $10 billion Corpus Christi project. Each train at these facilities is designed to have a peak capacity of 5 million tons per year, equivalent to about 694 million cubic feet per day (cf/d) of gas, and a baseload capacity of 4.5 million tons per year. 

The first three trains at Sabine Pass have been operating near their peak capacity since March 12, with gas intake at the facility averaging about 2.2 billion cubic feet per day (Bcf/d) since then. The upcoming Train 4 at Sabine Pass is anticipated to increase gas intake by 33 percent, closely watched by both the domestic gas and international LNG markets. This expansion is expected to enhance the ability to sell additional cargo on the spot market, further cementing Cheniere's position in the global LNG trade.

  1. Freeport Import LNG

As of 2024, the terminal has a total annual capacity of about 15 million metric tons.

The Freeport LNG terminal in Texas can liquefy up to 2% of the U.S. daily gas production when running at full capacity, enough to power around 11 million homes. The process involves cooling natural gas to -256 degrees Fahrenheit (-160 degrees Celsius) to liquefy it, making it easier to transport globally on specialized tankers. 

Over the past few years, the terminal's utilization has varied. In the year leading up to June 2022, it operated at 80% of its full capacity, which is 2.2 Bcfd, averaging about 1.820 Bcfd. However, in the following year, the average dropped to 1.625 Bcfd or 72% of its capacity. This decline in activity placed Freeport's Quintana plant among the lowest in utilization rates in the U.S., with only Venture Global LNG's Calcasieu Pass in Louisiana showing a comparable rate of 80% during its commissioning phase.  

An explosion in June 2022 temporarily halted operations at Freeport. By November 2023, the facility was back to full output, and exports for the year rose by 14.7% to 88.9 million tonnes, compared to 77.5 million tonnes the previous year. 

The Freeport LNG regasification terminal is jointly owned by Chubu Electric Power Co, Freeport LNG Investments, Osaka Gas Co, and Tokyo Electric Power Co Holdings, and operated by Freeport LNG Development. It started operations in 2008 and has a regasification capacity of 730 Bcf. 

The terminal has faced several challenges recently, including maintenance issues that began with an electric motor failure in mid-January during a winter storm affecting its Train 3 liquefaction unit. This unit has had further interruptions, though there has been a recent uptick in activity, with expected feedgas volumes of around 830 million cubic feet as of April 29, based on current nominations. This figure may be adjusted later depending on operational needs.

  1. Golden Pass Import LNG

ExxonMobil and QatarEnergy are working together to build a project that can produce up to 18.1 million metric tons per year. 

The Golden Pass LNG project, a joint venture between ExxonMobil and QatarEnergy, is set to significantly expand its operations by 2025. This Texas-based facility, which currently functions as an LNG regasification terminal with a capacity of 730 Bcf, is transitioning to become a major LNG export hub.

Developers plan to bring the first two of three new trains online in 2025. These trains are being constructed at the existing import terminal site, which is being converted for export purposes. Each train will have a nominal capacity of 0.68 Bcf/d, with a peak capacity of 0.80 Bcf/d. According to the schedule, Trains 1 and 2 are expected to start operations in the second and fourth quarters of 2024, respectively.

The addition of these two trains, along with other developments like the Plaquemines Phase 1 project, will contribute an additional 2.7 Bcf/d of nominal LNG export capacity, or 3.2 Bcf/d at peak. 

This expansion is part of a broader increase in U.S. LNG capacity, which is projected to rise by 91% from current levels 

  1. Cove Point Import LNG

About 80% of Cove Point's capacity, equivalent to 4.6 Mtpa, is secured under long-term contracts currently. 

The Cove Point LNG regasification terminal, located in Maryland, USA, is primarily owned by Berkshire Hathaway Energy Co and Dominion Energy, among others. It began operations in 1978 and has a regasification capacity of 657 Bcf. Berkshire Hathaway Energy also operates this facility.

The terminal includes the Cove Point II LNG Liquefaction terminal, which sources its feed gas from the Marcellus and Utica shale formations. This facility is equipped with one liquefaction train that has a production capacity of 5.75 million tons per annum (Mtpa), a figure that is expected to remain stable through 2030.

  1. Lake Charles Import LNG

The Lake Charles Import LNG regasification terminal, located in Louisiana, USA, started operations in 1981. Operated by Lake Charles LNG Co, the terminal is undergoing a transformation. Owned by Energy Transfer, the terminal is being converted from an import and regasification facility into an LNG export terminal. This project on the US Gulf Coast has approximately 9 Bcf of LNG storage capacity and features re-gasification facilities, an above-ground storage capacity of about 430,000m3, two deep-water docks that can handle ships up to 217,000m3, and a deep-water turning basin. 

Energy Transfer LP recently announced three non-binding Heads of Agreement (HOAs) for long-term LNG offtake totaling 3.6 million metric tons per annum (Mtpa) from its Lake Charles LNG project. These agreements include a deal with a Japanese consortium to purchase 1.6 Mtpa for a 20-year term, potentially converting to an equity stake. Chesapeake Energy Marketing LLC has agreed to supply enough natural gas to produce 1.0 Mtpa of LNG for 15 years, with post-liquefaction LNG purchased by Gunvor Singapore Pte Ltd at a price indexed to the Japan Korea Marker (JKM) for the same duration. Another agreement involves a U.S. customer for a tolling arrangement of 1.0 million metric tons per annum (mtpa) over a 15-year term. 

  1. Elba Island Import LNG

The terminal boasts an LNG regasification capacity of 641 Bcf. 

The Elba Island Import LNG regasification terminal in Georgia, USA, owned by Kinder Morgan and operated by Southern Natural Gas Co, has been operational since 1972. 

Elba Island facility includes 10 movable modular liquefaction units, with a combined capacity of about 2.5 million metric tons per annum (mtpa) of LNG, equivalent to roughly 350 MMcf per day of natural gas. 

The project reached full commercial operations in August 2020 and has secured a 20-year contract with Shell. Elba Island, one of only two East Coast U.S. LNG exporters, is authorized by the U.S. Department of Energy to export over 300 billion cubic feet of LNG annually. Out of this total, 182.5 billion cubic feet can be exported to 20 countries with which the U.S. has free trade agreements, and another 130 billion cubic feet can be exported to non-FTA nations. 

  1. Cameron Import LNG

As of 2024, the Cameron Export terminal, equipped with three trains, boasts an LNG production capacity of 13.5 million tons per annum (Mtpa), projected to increase to 20.3 Mtpa by 2030.

The Cameron LNG regasification terminal, located in Louisiana, USA, began operations in 2009. Owned by a consortium including Mitsubishi Corp, Mitsui & Co, Nippon Yusen Kabushiki Kaisha, Sempra Energy, and TotalEnergies, the terminal has a regasification capacity of 548 BCF. 

Currently, 23.63% of its capacity, equating to 3.19 Mtpa, is secured through long-term contracts. The facility is undergoing an expansion to add 6.8 Mtpa to its capacity. 

In 2023, TotalEnergies emerged as the leading exporter of U.S.-origin LNG, exporting over 10 million tonnes from its 16.6% stake in Cameron LNG. During a week in April 2024, Sempra Infrastructure’s Cameron LNG terminal dispatched three cargoes, while Venture Global LNG’s Calcasieu Pass and the Elba Island terminal each shipped two cargoes. 

  1. Gulf Import LNG

The terminal has a regasification capacity of 548 Bcf.

The Gulf Import LNG regasification terminal in Mississippi started operations in 2011 and is owned by Kinder Morgan, Thunderbird Resources, and Zenith Energy, among others, with Kinder Morgan also serving as the operator. The terminal features a dock facility initially permitted to receive LNG vessels up to 170,000 cubic meters, with designs to handle up to 250,000 cubic meters. As part of a proposed liquefaction and export project, this limit is set to increase to 208,000 cubic meters.

The Gulf Coast region, especially areas like Lake Charles, Corpus Christi, and Port Arthur, has seen significant development due to the LNG industry. This year, two new Gulf Coast terminals are expected to start their first shipments, with five additional terminals under construction. These upcoming facilities will collectively add approximately 9.7 Bcfd of LNG export capacity, marking a significant expansion in the region's LNG capabilities. 

  1. Saint John Import LNG

Saint John LNG, located in New Brunswick, Canada, serves a critical role by supplying 20% of the northeast U.S.'s natural gas needs and meeting Canadian demands. 

The facility became operational in 2009 and is managed by Canaport LNG, with ownership held by Repsol. It has a regasification capacity of 438 BCF.

The terminal can dispatch a maximum of 1.2 BCF or 28 million cubic meters of natural gas per day. Repsol’s Saint John LNG unit has noted that constructing the interconnecting pipelines needed to deliver natural gas to LNG export facilities would take at least three years. Additionally, Saint John LNG is planning to enhance its facility by adding a liquefaction capacity of 2 million tons per annum (Mtpa).

  1. Energia Costa Azul

The second phase of ECA LNG is being planned, which is expected to have an export capacity of 12 Mtpa by 2024, significantly increasing the terminal's output. 

Energia Costa Azul (ECA) LNG regasification terminal, owned and operated by Sempra Energy, is situated in Baja California, Mexico. It began operations in 2008 and has a regasification capacity of 365 BCF. ECA LNG was notable for being the only LNG-export project globally to have reached a final investment decision (FID) in 2020.

Phase 1 of ECA LNG, which is a single-train liquefaction facility, is designed to have a nameplate capacity of 3.25 million tons per annum (Mtpa) of LNG. This phase has secured 20-year sale and purchase agreements with TotalEnergies and Mitsui & Co., Ltd. for a combined total of 2.5 Mtpa of LNG. Sempra aims to begin commercial operations of this phase by the summer of 2025. This first phase will include one liquefaction train with an initial offtake capacity of 2.5 Mtpa (0.33 Bcf/d). Sempra Infrastructure holds an 83.4% working interest in the project. 



In 2023, the United States topped the charts as the world's biggest producer and exporter of natural gas, sending off an impressive 86 million tons of LNG. 

This high volume primarily came from five major terminals in Louisiana and Texas, averaging exports of 11.6 billion cubic feet per day (Bcfd). 

Europe continued to be the primary market for these exports, taking in 67% of the total or 7.7 Bcfd. During the winter heating season, Europe experienced a slight imbalance in its gas supply and demand. In November, the region was using about 20 MMcfd more than what was being stored, according to Norway's Rystad Energy. Starting in September, Europe's LNG imports began to increase, hitting a peak of 2.8 MMcfd in the second week of November.

For the year, the U.S. managed to export around 90 million metric tons of LNG, up by 15% from 2022. This boost in exports was partly because the Freeport LNG plant on the U.S. Gulf Coast resumed full operations after being offline in 2022. 


In 2024, the U.S. may see an additional 25-35 million tons per year (mt/yr) of LNG capacity reach a FID, but this could potentially be the last significant wave of projects due to escalating risks. 

  • In January 2024, the U.S. government announced a pause on new licenses for export terminals. 
  • Wood Mackenzie’s analysis suggests existing production can meet major European gas demands.
  • The freight markets are expected to remain volatile, with significant daily price fluctuations.

Three major U.S. projects are nearing FID: Venture Global’s Calcasieu Pass 2 (CP2) facility, Delfin Midstream’s first floating LNG (FLNG) vessel, and the independent Commonwealth LNG terminal. Together, these projects could add up to 23 mt/yr of LNG capacity. All three have received necessary regulatory approvals (FERC for CP2 and Commonwealth, MARAD for Delfin FLNG), and are finalizing or have secured the offtake and tolling agreements needed for FID.

Commonwealth LNG and Delfin FLNG have been actively signing financing and offtake agreements, and CP2 has just received FERC environmental approval. CP2 and Commonwealth LNG are now aiming to secure Department of Energy (DOE) approval before moving forward with FID. Delfin FLNG faces a decision on whether to pursue FID based on starting construction to secure an extension for its current deadline or to apply for a new export license, which would delay the project significantly.

Meanwhile, U.S. LNG exports saw an increase in the week ending April 24, with 22 LNG carriers departing from U.S. plants, one more than the previous week. The total capacity of these LNG vessels was 79 Bcf. Average natural gas deliveries to U.S. LNG export terminals rose by 4.9% week over week, averaging 11.5 Bcf/d, according to data from S&P Global Commodity Insights. Deliveries in South Louisiana increased by 4.1% to 8.2 Bcf/d, and in South Texas by 14.3% to 2 Bcf/d, while deliveries outside the Gulf Coast remained steady at 1.3 Bcf/d. 

From January 1 to April 29, 2024, U.S. LNG exports reached 30.55 million mt, setting a record high for the January-April period since the dataset began in 2016. This compares to 29.46 million mt in 2023 and 28.39 million mt in 2022 during the same period. Lower feedgas demand has also helped keep regional natural gas storages well-stocked, with major liquefaction terminals in the U.S. averaging deliveries of about 12.19 Bcf/d during the week ended April 2024, down from 13.89 Bcf/d during the same week in 2023.

Additionally, the Freeport LNG facility has been undergoing maintenance for much of the year, starting with an electric motor failure in its Train 3 liquefaction unit during a winter storm in mid-January. Recently, feedgas volumes have rebounded, with Freeport set to receive around 830 MMcf on April 29. 


LNG Export Growth 

  • 2024: Expected 2% increase in LNG exports compared to the record year of 2023.
  • 2025: Anticipated 18% rise due to new LNG terminals becoming operational.

Liquefaction Capacity  

By the end of 2024, U.S. LNG nominal liquefaction capacity is projected to increase to 14.1 Bcf/d.

Peak capacity is expected to reach 17.0 Bcf/d across nine U.S. LNG export facilities.

Development Projects 

Six ongoing LNG projects in the U.S. are set to boost capacity by 80% from 14 Bcf/d in 2024 to over 25 Bcf/d by 2028.

Key projects nearing completion by year-end 2024

  • Venture Global’s Plaquemines Phase 1 (Louisiana): Adds 3.1 Bcf/d, increasing total capacity by about 22%.
  • Cheniere Energy’s Corpus Christi Liquefaction Stage 3 (Texas).

The global demand for LNG has grown, prompting significant investment in U.S. LNG export projects.

Strategic Infrastructure Developments

  • New LNG facilities have been strategically established along the Gulf Coast.
  • Proximity to deep-water ports and major natural gas production areas like the Permian and Haynesville basins.
  • Midstream companies have been crucial, connecting production to export facilities and participating in LNG liquefaction.

Net Exports and Market Outlook 

  • 2024 Forecast: Net exports of U.S. natural gas to grow 6% to 13.6 Bcf/d.
  • 2025 Forecast: Net exports are expected to increase by another 20% to 16.4 Bcf/d.

LNG Exports 

  • 2024: Forecasted to increase by 2% to average 12.2 Bcf/d.
  • 2025: Forecasted to grow by an additional 18%.

Pipeline Exports are expected to grow by 3% in 2024 and by 4% in 2025.

Pipeline Imports are projected to decline by 0.4 Bcf/d in 2024 and then increase slightly by 0.1 Bcf/d in 2025.

LNG Export Boom in the US

Since starting in 2016, U.S. LNG exports have grown significantly. Last year, the U.S. exported 86 million tons of LNG. This increase was supported by the start-up of the Calcasieu Pass LNG facility and the resumption of operations at Freeport LNG. In December 2023, exports reached a record high of 8.6 million tons in just one month.

Over 70 million tons per year (mmtpa) of baseload export capacity is under construction across several projects including Golden Pass, Corpus Christi Stage 3, Plaquemines, Port Arthur, and Rio Grande. Three of these projects secured their final investment decision (FID) last year, attracting $40 billion in investment.

U.S. LNG projects with Pre-FID status (2024):



Design Capacity (Bcf/d)

DOE-Authorized Export Quantity, FTA Countries (Bcf/d)

DOE-Authorized Export Quantity, Non-FTA Countries (Bcf/d)

FERC-Authorized Export Quantity (Bcf/d)

Cameron LNG Train 4

Cameron LNG, LLC





Magnolia LNG

Glenfarne Group





Lake Charles LNG

Energy Transfer, LP





Driftwood LNG

Driftwood LLC (subsidiary of Tellurian, Inc.)





Freeport LNG Train 4

Freeport LNG





Texas LNG

Glenfarne Group





Rio Grande LNG (Phase 2)

NextDecade Corporation





Gulf LNG

Kinder Morgan et al.





Delfin FLNG

Fairwood Group





Alaska Gasline

Alaska Gasline Development Corporation





Source: CSIS

The U.S. and Qatar are projected to account for 80% of the global LNG supply increase by 2030. However, with LNG export capacity expected to nearly double by 2028, there's a growing need to consider the potential price impacts on the market. Presently, gas flows to LNG export facilities already exceed 14 Bcf/d, about 13% of U.S. dry gas production. This figure could rise to 20% in the next five years, prompting questions about the broader impact on other industries.

LNG Pause

On January 26, President Biden announced a temporary halt on approvals for pending LNG projects pending further review. Despite this pause, the U.S. is still on track to significantly increase its LNG production capacity. Current construction projects are set to add 70 million tons of LNG annually, boosting the total capacity to 160 million tons by 2028. However, the pause will impact the decision-making process for about a dozen proposed terminals, which represent an additional capacity of roughly 50 million tons per year.

In the U.S., LNG is sold on a free on board (FOB) basis, which means buyers—typically other oil and gas companies, utilities, and traders—take ownership at the export terminal. They are responsible for arranging shipping and can sell the LNG in various markets. This setup allows buyers to send LNG cargoes to both Europe and Asia, facilitating arbitrage opportunities between these markets and helping to globalize LNG trade.

As of now, U.S. LNG exports to Europe remain secure, but Europe's commitment to significantly reduce its gas consumption casts uncertainty over future demand, especially in the 2030s and beyond.

In March 2024 showed that net exports of natural gas from the U.S. increased by 21% from the previous year and accounted for 12.7% of the total U.S. natural gas demand in 2023. This rise was partly due to an increase in FERC-authorized export liquefaction capacity from 11.2 Bcfd to 14.2 Bcfd. This expansion has also driven pipeline construction across the south-central U.S., with over 43% of the pipeline capacity added in the last five years situated in this region, primarily to supply LNG export terminals.

In 2023, the U.S. exported 4.3 trillion cubic feet of natural gas to 40 countries, with nearly two-thirds of the total U.S. LNG volumes shipped to Europe. January 2024 alone saw 156 LNG export events, including 31 via smaller tank containers from Florida ports to destinations like Haiti, the Bahamas, and Barbados, and 125 via larger LNG vessels heading to countries including Belgium, Turkey, Thailand, Lithuania, Brazil, China, and Greece.

In January 2024, the top U.S. LNG export facilities by the number of sailings were:

Cheniere/Sabine Pass Liquefaction in Sabine Pass, LA 

39 sailings

Freeport LNG Expansion in Freeport, TX 

18 sailings

Cheniere Marketing in Corpus Christi, TX 

18 sailings

Venture Global Calcasieu Pass in Cameron, LA 

15 sailings

Cameron LNG in Cameron, LA 

12 sailings

Mitsui & Co./Cameron LNG in Cameron, LA 

9 sailings

ST Cove Point & Gail Global in Cove Point, MD 

7 sailings

Shell NA/Southern LNG at Elba Island, GA 

6 sailings

By 2030, the U.S. is expected to operate 11 LNG export plants, with the total value of LNG exports projected to reach $100 billion. This figure would represent 3% of the entire U.S. trade balance. According to the Center for LNG, without these exports, the U.S. trade deficit in August 2022 would have been $72 billion, or 7.5% higher.

Projects continue to advance, including the Rio Grande LNG Phase 1 project in Brownsville, led by NextDecade Corp. This project has secured $18.4 billion in financing, making it the largest greenfield energy project financing in U.S. history.

LNG and Methane Emissions

The U.S. Environmental Protection Agency recently introduced a regulation expected to cut methane emissions from the oil and gas industry by 80% by the end of the decade.

Some critics of LNG argue that methane emissions from U.S. natural gas production might negate its climate benefits compared to coal. Research suggests that methane leakage rates would need to exceed about 4% to offset the environmental advantages of natural gas over coal.

Addressing methane emissions from the oil and natural gas supply chains is seen as one of the most effective ways to reduce greenhouse gases and stabilize the climate. However, the actual methane leakage rates necessary to eliminate the climate benefits of U.S. natural gas are significantly higher than the average rates recorded across the national energy sector.

For instance, the often-cited methane intensity rate for U.S. natural gas production is 2.3%. This number, mentioned in the Biden White House’s Methane Action Plan, is based on data from 2015 and does not reflect the tighter methane controls implemented in the U.S. over the past decade.

New technologies are transforming how we monitor and manage methane emissions. Tools like ground-level sensors, drone flights, aerial surveys, and satellite imagery now offer detailed insights into where and how methane emissions occur.

Conclusion: Is it time to ease up on promoting natural gas? 

Proponents of the LNG industry claim that natural gas is a less polluting alternative to coal, citing that it produces roughly half the emissions when used to generate electricity. They argue that substituting coal with gas could lower emissions. However, contrasting studies draw attention to the methane emissions from pipeline leaks, which could potentially make natural gas more detrimental to the climate than coal.

Even if these methane leaks were controlled, using gas for power generation would still contribute to global warming. Moreover, countries that shift to natural gas now might become dependent on it for many years, making them vulnerable to unpredictable fluctuations in its price.

Instead of using natural gas as a transitional fuel, it might be wiser to skip directly to renewable energy sources. If countries adopt this approach, the LNG industry might end up expanding its production capacity without a corresponding market demand, despite industry forecasts of continued growth.

If you are looking for more information about energy companies, their assets, and energy deals, please, contact our sales office, Tel. 619-349-4970 or SCHEDULE A DEMO to learn how Rextag can help you leverage energy data for your business.


LNG Natural Gas

Look At The Future Of American And Appalachian Gas Production


The crux of the matter is rather simple: productivity gains of local energy operators have been stable not only because they are drilling better acreage, but also because players finally realized capital efficiency gains. And even if some new obstacles impede Appalachia's growth at the same rate as the Permian or Haynesville, it does not detract from the value of the Marcellus and Utica basins. The Appalachians will still be the top producers at a very competitive pace as long as commercial inventory exists. After all, as long as there is commercial inventory, somebody will have to drill.

US Natural Gas May Update: Current Trends and Market Outlook


According to the latest report from the EIA, working natural gas stocks in the United States saw a substantial increase. Stocks rose by 79 billion cubic feet (Bcf), bringing the total to 2,563 Bcf. This marks a significant year-over-year increase of 444 Bcf. Current stockpiles are considerably above the five-year average, having grown by 640 Bcf compared to the average of 1,923 Bcf.


Recently, the progress toward an energy transition is hitting a snag. Sales of electric vehicles are decelerating, and the growth in wind and solar power needs to be keeping pace with expectations. To make matters more challenging, electricity prices are climbing when they were expected to fall. Amidst these setbacks, the oil and gas sectors are proving resilient. According to BP's latest energy outlook, not only are these energy mainstays here to stay, but their demand is expected to remain relatively high even after reaching a peak. Interestingly, BP forecasts that oil demand will reach its zenith next year, marking a critical moment in energy consumption trends. This isn't the first time BP has projected a peak in oil demand. Back in 2019, their review anticipated a decline in demand growth, but the prediction fell flat. Instead, oil demand surged to unprecedented levels following the end of the global pandemic lockdowns, defying previous forecasts and underscoring the enduring dominance of traditional energy sources in the global market.


Texas energy companies are picking up the pieces after Hurricane Beryl, an early Category 5 hurricane, hit the U.S. Gulf Coast earlier this week. However, it weakened to Category 1 by the time it made landfall in Texas. The hurricane brought heavy rainfall and sparked fears of storm surges, flooding, and tornadoes. As Hurricane Beryl neared, the natural gas supply to Freeport LNG’s export facility in Texas nearly stopped the day before the storm struck. Houston was particularly hard-hit, with the storm knocking out power for two million residents. CenterPoint Energy, a key power provider in the area, felt the brunt of the hurricane but aimed to have power restored to half the affected customers by the following day.


The total number of drilling rigs actively exploring and producing oil and natural gas in the United States increased to 585 for the week ending July 5, up from 581 the previous week. Despite this recent uptick, the current count still falls short of last year's 680, indicating a slowdown in drilling activities. Analysts suggest that this reduction may reflect greater efficiency among shale producers, who now require fewer rigs. Nonetheless, concerns remain about whether some producers have enough viable drilling land

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