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15 April 2025
World Oiloil-gas
Apr 15, 2025World Oil
Halliburton and Nabors Industries achieved the first fully automated surface and subsurface execution of rotary and slide drilling operations in Oman. The integration of the companies’ digital solutions delivered land-based, closed-loop drilling solutions to improve operational efficiency, consistency and real-time decision-making capabilities.
The closed-loop drilling execution earned both companies the 2025 Digital Enabler of the Year Award and represents a step forward in automation in the region.
Halliburton and Nabors Industries achieved the first fully automated surface and subsurface execution of rotary and slide drilling operations in Oman. The integration of the companies’ digital solutions delivered land-based, closed-loop drilling solutions to improve operational efficiency, consistency, and real-time decision-making capabilities.
Halliburton’s LOGIX™ automation and remote operations solutions, and Nabors SmartROS® rig operating system enabled seamless orchestration of drilling parameters, real-time data analytics, integrated experience management, and remote control of operations.
“We delivered operational efficiency, consistency, and reliability,” said Steve Haden, senior vice president, Project Management, Halliburton. “The wells were delivered ahead of plan with a higher average rate of penetration and lower non-productive time. This milestone demonstrates our leadership in drilling automation.”
“The success we are seeing in Oman is a testament to the power of collaboration as we work together to drive automation across the industry to improve safety and efficiency. This is just the beginning, and we are excited to continue to push the boundaries of innovation to achieve autonomous drilling,” said Subodh Saxena, senior vice president, Canrig and Nabors Drilling Solutions.
This collaboration between Halliburton and Nabors in the Middle East led to drilling performance optimization and reduction of well construction time.
Lead image courtesy of Nabors
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Aramco Secures $10 Billion Blackrock-Led Investment For Jafurah Gas Pipeline NetworkA BlackRock-led consortium is set to inject $10 billion into the vital pipeline infrastructure of Saudi Aramco's Jafurah gas project. This significant financial commitment highlights the central role of pipelines in expanding Saudi Arabia's natural gas production and its strategic shift towards a more diversified energy mix.
The investment is anticipated to mirror prior infrastructure deals from 2021, where BlackRock also participated in Aramco's gas pipeline assets. In those previous arrangements, investors acquired a 49% stake in new entities, such as Aramco Gas Pipelines Co., which then held 20-year leasing rights over existing pipeline networks. These entities lease the usage rights back to Aramco, ensuring a steady revenue stream for investors through tariffs on gas flows, underpinned by minimum volume guarantees. Aramco, however, maintains a controlling 51% stake and full operational command of these crucial assets.
The Jafurah project itself is a cornerstone of Aramco's plan to boost its gas production capacity by 60% from 2021 levels by 2030, representing a total investment projected to surpass $100 billion over the next 15 years. Crucially, this expansion necessitates the construction of extensive new infrastructure, including an estimated 1,500 kilometers (932 miles) of new pipelines, along with gas processing plants and other facilities. These pipelines are indispensable for transporting gas from the Jafurah field, which is expected to become one of the world's largest shale gas projects outside the United States.
This strong focus on natural gas infrastructure, particularly pipelines, underscores its perceived role as a "bridge fuel" in the global energy transition. By enabling increased natural gas utilization, Saudi Arabia aims to displace more carbon-intensive energy sources, thus contributing to its net-zero emission targets. The substantial investment from the BlackRock-led group signals confidence in the long-term stability and strategic importance of these pipeline assets within the evolving global energy landscape.
Pipeline Technology Journal
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18 July 20252 min readAramco Secures $10 Billion Blackrock-Led Investment For Jafurah Gas Pipeline Network
Pipeline Technology Journal
18 July 2025
oil-gas
Australia’S Orica Hydrogen Hub Secures $283 Million To Advance Green Hydrogen Exports(Reuters) — Australia said on July 3 it would invest A$432 million ($283.82 million) in a green hydrogen project led by Orica, the world’s largest explosives maker, backing the emerging industry amid a wave of delays and cancelled projects across the country.
The funding will support the Hunter Valley Hydrogen Hub, which aims to decarbonize Orica’s nearby ammonia and explosives manufacturing operations and eventually supply the green fuel and green ammonia for export.
Climate Change and Energy Minister Chris Bowen said the funding for the project on the east coast helped secure Australia’s energy future, with the government seeing green hydrogen as key to its net-zero goals.
“By switching from gas to green hydrogen, the project will also significantly cut emissions from Orica’s ammonia production facility and help produce green ammonia for domestic use across mining, agriculture and manufacturing sectors,” Bowen said in a statement.
It is a boost for Australia’s struggling green hydrogen industry after a series of delays and exits cast doubt on its viability.
On Sunday, plans to build a A$12.5 billion CQ-H2 plant in the state of Queensland collapsed after its lead developer, state-government owned energy company Stanwell, ended its involvement. It was one of the country’s largest and most advanced projects.
Orica’s Hunter Valley Hydrogen Hub, once a joint venture with Origin Energy ORG.AX, faced a major setback last year when the power producer exited, citing cost concerns and headwinds in the green hydrogen market.
Orica said the government support was “essential” to bridging the project’s “commercial gap”.
The explosives maker added that it had received strong interest from potential project partners in the past few months and would work towards a final investment decision “in due course”.
“We hope to further contribute to our domestic and international customers' decarbonization goals by offering low-carbon products, while supporting Orica’s next phase of decarbonization,” CEO Sanjeev Gandhi said.
The first phase of the hub is expected to produce up to 12 tonnes of green hydrogen per day using a 50 megawatt electrolyzer powered by renewable energy.
($1 = 1.5221 Australian dollars)
Pipeline Gas Journal
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18 July 20252 min readAustralia’S Orica Hydrogen Hub Secures $283 Million To Advance Green Hydrogen Exports
Pipeline Gas Journal
18 July 2025
oil-gas
$10 Billion Deal Set For Aramco’S Jafurah Gas Pipelines, Plant(Reuters) — Saudi Aramco is close to a deal to raise around $10 billion from a group led by BlackRock that has been set up to invest in the infrastructure of Aramco's Jafurah gas project, two people with knowledge of the matter told Reuters.
The agreement would be the latest in a series of financial arrangements, akin to borrowing, that allow Gulf oil producing countries to raise money to diversify their economies while promising investors a stable revenue stream.
The two people said the latest transaction was expected to be similarly structured to two Aramco infrastructure deals in 2021, including one in which BlackRock invested in Aramco's gas pipeline networks, allowing the Saudi company to generate funds.
Aramco kept control of the underlying infrastructure while the investors earned tariffs from the oil firm for the use of the pipelines.
Both sources spoke on condition of anonymity because the talks are private. They did not say when the deal might be finalized. Aramco and BlackRock declined to comment.
The $100 billion Jafurah project, potentially the biggest shale gas project outside the United States, is central to Aramco's ambitions to become a major global player in natural gas and to boost its gas production capacity by 60% by 2030 from 2021 levels.
The Jafurah assets underpinning the deal include gas pipelines and a gas processing plant, one of the sources said.
Aramco has long been the biggest source of the kingdom's revenues. Saudia Arabia has been seeking to diversify its economy as oil prices LCOc1 have come under pressure from global economic uncertainty that could further reduce demand.
They have also been depressed by increased output from the Organization of the Petroleum Exporting Countries, led by Saudi Arabia, which is striving to boost market share.
Earlier this month, Reuters reported that Aramco was seeking to sell up to five gas-fired power plants to raise funds.
Previous Deals
In 2021, BlackRock and EIG were among investor groups that took stakes in companies that leased usage rights in Aramco’s gas and oil pipeline networks. The groups leased them back to Aramco for a 20-year period in two separate deals, helping the Saudi company to raise nearly $28 billion.
Described as lease and leaseback transactions by Aramco at the time, they were structured as a form of borrowing, Robin Mills, chief executive of consultancy Qamar Energy told Reuters.
"The pipeline deals were basically securitization" and not a sale of the asset, whose ownership remained with Aramco, Mills said.
In those deals the groups took 49% stakes in subsidiaries Aramco Oil Pipelines and Aramco Gas Pipelines, in which Aramco retains 51% stakes. The subsidiaries receive a tariff from Aramco for flows of crude and natural gas, backed by minimum commitments on throughput.
The deals followed other transactions in the region, including Abu Dhabi's ADNOC sale of minority stakes in the companies owning the leasing rights to its oil and gas pipelines.
Pipeline Gas Journal
oil-gas
17 July 20253 min read$10 Billion Deal Set For Aramco’S Jafurah Gas Pipelines, Plant
Pipeline Gas Journal
17 July 2025
oil-gas
Blackstone To Invest $25 Billion In Co-Located Data Centers, Gas Plants In Pennsylvania(Reuters) — Blackstone plans to invest $25 billion in developing data centers and power plants in Pennsylvania, President and Chief Operating Officer Jon Gray said at a panel at the Energy and Innovation Summit in Pittsburgh on July 15.
Blackstone had identified several sites to build the energy-intensive centers, Gray said, adding that the private equity firm also plans to partner with an electric utility to build multiple natural gas power generation facilities to fuel the data centers in Pennsylvania.
Big Tech is fueling a turnaround in U.S. power consumption with the expansion of data centers, which are needed to train and roll out artificial intelligence.
One of the biggest roadblocks in the race to expand artificial intelligence technologies are the long wait times, caused by supply chain constraints and permitting, to power data centers. Locating data centers directly at the sites of power plants, an arrangement known as co-location, can potentially cut down time to power.
Blackstone plans to focus on co-located projects in Pennsylvania, Gray said.
"What makes us so excited about this area is the idea that you can co locate data centers directly next to the source of power and that's really the special sauce here is being able to put these things together," Gray said.
Pipeline Gas Journal
oil-gas
15 July 20252 min readBlackstone To Invest $25 Billion In Co-Located Data Centers, Gas Plants In Pennsylvania
Pipeline Gas Journal
15 July 2025
oil-gas
South Korean Ypp Plans To Invest Up To $3.1B In Green Hydrogen Production In KazakhstanDeputy Chairman of the Management Board of JSC “NC “KAZAKH INVEST,” held a meeting with John M. Bek, Chairman of the Board of the South Korean engineering company YPP Corporation. During the meeting, the parties signed a framework agreement on cooperation for the implementation of a green hydrogen production project in Kazakhstan.
The parties confirmed their intent to implement a major investment project — Green Energy Complex — in the Republic of Kazakhstan, aimed at creating a full-cycle production of green hydrogen and ammonia using renewable energy sources (RES). The total investment may reach up to $3.1 billion, depending on the project model and location conditions.
The project provides for the construction of wind and solar power plants with a total capacity of up to 2 GW, as well as the installation of electrolysis and ammonia production units. Production capacities are expected to reach up to 75,000 tons of green hydrogen, some of which are then converted into 310,000 tons of green ammonia annually. Part of the output will be used domestically, with the majority intended for export.
During the meeting, Azamat Kozhanov noted that the project aligns with Kazakhstan’s strategic priorities and ambitious plans for developing the hydrogen energy sector.
“We see a strong and sustained interest from international companies in implementing green energy and hydrogen projects. Kazakhstan has tremendous potential — up to 1,820 billion kWh per year for wind and 2.5 billion kWh for solar. Dozens of initiatives are already underway, and we believe that partnerships like the one with YPP will turn this potential into tangible production, exports, and new jobs,” he said.
The project also involves the development of local infrastructure, including energy storage systems, water supply, logistics, and potential applications of hydrogen in energy — particularly through modernization of CHP plants in the Almaty region.
In turn, YPP founder John M. Bek expressed gratitude for the support from the Government of Kazakhstan and stated:
“Kazakhstan has unique natural conditions and an investment climate favorable for the development of hydrogen energy. We view the Republic of Kazakhstan as a strategic partner and intend to implement a project that combines Korea’s best technologies with global approaches to sustainable production.”
The agreement paves the way for a deeper elaboration of the investment model, conclusion of an investment agreement, and formation of partnerships with relevant organizations, including potential offtakers such as Samsung C&T.
Gulf Oil and Gas
oil-gas
15 July 20252 min readSouth Korean Ypp Plans To Invest Up To $3.1B In Green Hydrogen Production In Kazakhstan
Gulf Oil and Gas
15 July 2025
oil-gas
Adnoc Gas Signs $400M Lng Deal With Germany’S SefeAdnoc Gas has signed an agreement with Germany’s Securing Energy For Europe (Sefe) to supply liquefied natural gas for three years.
The UAE’s state-owned oil and gas company will sell more than 700,000 metric tonnes of LNG from its Das Island liquefaction facility valued at $400 million, with deliveries due to start this summer, Adnoc Gas said in a statement.
The Das Island’s LNG plant has a production capacity of 6 million tonnes per year. More than 3,500 cargoes have been shipped worldwide since operations began in 1977.
“This new medium-term LNG contract builds on the long-term supply agreement with Adnoc that we signed last year, thereby adding another flexible source of LNG to our portfolio,” said Frederic Barnaud, chief commercial officer of Sefe.
The agreement allows Sefe to decide on delivery destinations at its discretion, the statement said.
Adnoc already has ties with Germany. It has been in talks since last year to buy chemicals company Covestro, with approval by the EU expected to be ratified soon.
And in May last year it signed a 15-year LNG supply agreement with energy major Energie Baden-Württemberg AG.
In April Reuters reported that China’s ENN Natural Gas and state-run Zhenhua Oil have each signed deals to buy LNG from Adnoc.
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Arabian Gulf Business Insight
oil-gas
14 July 20252 min readAdnoc Gas Signs $400M Lng Deal With Germany’S Sefe
Arabian Gulf Business Insight
14 July 2025
oil-gas
Dangote Refinery To Build 1.6 Million-Barrel Fuel Storage Facility In NamibiaNigeria’s Dangote Refinery will construct fuel storage tanks in Namibia with a total capacity of at least 1.6 million barrels to supply petrol and diesel to Southern African countries.
The tanks will be located in the port city of Walvis Bay and will serve Botswana, Namibia, Zambia and Zimbabwe. The facility may also supply the south of the Democratic Republic of Congo.
The initiative is part of Dangote’s wider strategy to expand market access for fuel refined at its 650,000-barrel-per-day plant in Nigeria. Commissioned last year at a cost of $20 billion, the refinery has started supplying Nigeria’s domestic market and is gradually targeting new export destinations. Last month, a Dangote petroleum cargo reportedly left Nigeria for Asia, marking the refinery’s first known shipment outside West Africa. At full capacity, the refinery is expected to meet domestic demand and export surplus volumes.
Energy Capital Power
oil-gas
14 July 20251 min readDangote Refinery To Build 1.6 Million-Barrel Fuel Storage Facility In Namibia
Energy Capital Power
14 July 2025
oil-gas
Nigeria’S Oil Rig Count Climbs To 46, Backed By $8B In InvestmentNigerian regulation department the Nigerian Upstream Petroleum Regulatory Commission (NUPRC) has announced the country’s active number of oil rigs has increased to 46.
Up from eight in 2021, the increase follows over $8 billion in investments by oil producers between 2022 and 2025, resulting in the drilling of 236 wellbores.
Gbenga Kamolafe, Commission Chief Executive, NUPRC attributed the rise to the 2021 Petroleum Industry Act, the Project One Million Barrels initiative launched in 2024 and Executive Orders 40, 41 and 42 issued in 2024. According to Kamolafe, these reforms have boosted investor confidence, attracted capital and enabled regulatory efficiencies.
Nigeria’s oil production now averages over 1.7 million barrels per day (bpd), rising from 1 million bpd in 2021.
Kamolafe added that rigs are now active across all terrains – land, swamp and offshore – including deepwater fields.
The NUPRC emphasized that increased rig activity is a key metric of industry health, with sustained momentum driving progress toward the country’s 2.6-2.8 million bpd production target by 2026.
Nigeria’s rig count is expected to approach 50 by the end of 2025.
Energy Capital Power
oil-gas
14 July 20251 min readNigeria’S Oil Rig Count Climbs To 46, Backed By $8B In Investment
Energy Capital Power
14 July 2025
oil-gas
208-Mi Mississippi-To-Alabama (U.S.) Gas Pipeline Moves Into Ferc ReviewKinder Morgan’s Tennessee Gas Pipeline Company LLC (TGP) has filed a formal application with federal regulators to build the Mississippi Crossing Project (MSX), a $1.7-B natural gas pipeline expansion designed to deliver 2.1 billion cubic feet per day (Bft3d) of firm transportation capacity across Mississippi and Alabama.
The project includes 208 mi of new pipe — the centerpiece being a 199-mi, 42- and 36-in. mainline stretching from Greenville, Mississippi, to Butler, Alabama. Additional infrastructure includes three new compressor stations, multiple interconnects, and four metering facilities.
TGP submitted its Certificate of Public Convenience and Necessity application to the Federal Energy Regulatory Commission (FERC) on June 30, 2025, officially moving the project into the federal review phase. The filing followed the May 31 submission of all required environmental resource reports, which included consultations with regulatory agencies and other stakeholders.
The project is backed by strong market demand, with more than 90% of its capacity under long-term precedent agreements. Customers include major Southeast utilities and power generators such as Southern Company Services, Dominion Energy South Carolina, Tennessee Valley Authority, and the Municipal Gas Authority of Georgia. TGP affiliate Southern Natural Gas Company has secured 1.17 Bft3d of capacity to serve downstream users.
TGP is requesting FERC approval by July 1, 2026, with construction scheduled to begin in January 2027 and the pipeline expected to enter service by November 2028.
An independent market analysis submitted with the application projects that natural gas demand in Mississippi and Alabama will grow by 8% by 2030, driven by coal retirements, increased electricity generation and industrial activity. Current infrastructure in the region is operating near peak capacity.
In addition to enhancing energy reliability, the project is expected to provide a significant economic boost. TGP estimates it will support 4,760 to 9,820 average annual jobs across Mississippi, Alabama, and Georgia during construction, generating between $950 MM and $2.4 B in regional economic output.
To help reduce environmental and community impacts, approximately 28% of the proposed route will parallel existing infrastructure corridors, and several segments will be installed using horizontal directional drilling.
Gas Processing and LNG
oil-gas
14 July 20252 min read208-Mi Mississippi-To-Alabama (U.S.) Gas Pipeline Moves Into Ferc Review
Gas Processing and LNG
14 July 2025
oil-gas
Venezuela'S Pdvsa Reports $17.5 Billion In 2024 Oil Revenue As Exports Jump(Reuters) — Venezuelan state-run PDVSA's oil sales abroad in 2024 stood at $17.52 billion, according to a results document seen by Reuters on Friday, as exports jumped due to U.S. licenses allowing foreign partners to operate in the sanctioned OPEC member.
There are no comparative figures from previous years because PDVSA has not published its results since 2016, and it did not immediately respond to a request for comment.
Venezuela has some of the world's largest reserves of oil, but its crude output remains at a fraction of what it was a decade ago after a lack of investment, mismanagement at PDVSA and U.S. sanctions on Venezuela's energy industry since 2019.
The licenses to U.S. oil major Chevron and other foreign firms in Venezuela have allowed a slight recovery in oil output and exports since 2023.
In late May, however, Washington revoked those licenses to take Venezuelan crude bound for U.S. and European refineries.
PDVSA's crude oil and fuel exports averaged 805,500 barrels per day (bpd) last year, according to preliminary data from its 2024 financial and operational results.
That would be an over 15% hike from almost 700,000 bpd in 2023, according to data and documents viewed by Reuters.
According to PDVSA's results, the OPEC member produced an average of 952,000 bpd in 2024, compared with 783,000 bpd in 2023 reported by OPEC.
President Nicolas Maduro and his government have always rejected sanctions by the United States and others, saying they are illegitimate measures that amount to an "economic war" designed to cripple Venezuela.
Maduro and his allies have cheered what they say is the country's resilience despite the measures, though they have historically blamed some economic hardships and shortages on sanctions.
Crude production was above 1 million bpd in the first quarter of 2025, according to the results documents, and authorities have said that exports continue to perform normally.
In June, crude and fuel exports were 844,000 bpd, and were directed to China, according to shipping data and documents.
Pipeline Gas Journal
oil-gas
12 July 20252 min readVenezuela'S Pdvsa Reports $17.5 Billion In 2024 Oil Revenue As Exports Jump
Pipeline Gas Journal
12 July 2025
oil-gas
208-Mile Mississippi-To-Alabama Gas Pipeline Moves Into Ferc ReviewBy Mary Holcomb, Digital Editor
(P&GJ) — Kinder Morgan’s Tennessee Gas Pipeline Company, L.L.C. (TGP) has filed a formal application with federal regulators to build the Mississippi Crossing Project (MSX), a $1.7 billion natural gas pipeline expansion designed to deliver 2.1 billion cubic feet per day (Bcf/d) of firm transportation capacity across Mississippi and Alabama.
The project includes 208 miles of new pipe — the centerpiece being a 199-mile, 42- and 36-inch mainline stretching from Greenville, Mississippi, to Butler, Alabama. Additional infrastructure includes three new compressor stations, multiple interconnects, and four metering facilities.
TGP submitted its Certificate of Public Convenience and Necessity application to the Federal Energy Regulatory Commission (FERC) on June 30, 2025, officially moving the project into the federal review phase. The filing followed the May 31 submission of all required environmental resource reports, which included consultations with regulatory agencies and other stakeholders.
SEE ALSO: FERC OKs Construction on Mississippi Hub Gas Storage Expansion
The project is backed by strong market demand, with more than 90% of its capacity under long-term precedent agreements. Customers include major Southeast utilities and power generators such as Southern Company Services, Dominion Energy South Carolina, Tennessee Valley Authority, and the Municipal Gas Authority of Georgia. TGP affiliate Southern Natural Gas Company has secured 1.17 Bcf/d of capacity to serve downstream users.
TGP is requesting FERC approval by July 1, 2026, with construction scheduled to begin in January 2027 and the pipeline expected to enter service by November 2028.
An independent market analysis submitted with the application projects that natural gas demand in Mississippi and Alabama will grow by 8% by 2030, driven by coal retirements, increased electricity generation, and industrial activity. Current infrastructure in the region is operating near peak capacity.
In addition to enhancing energy reliability, the project is expected to provide a significant economic boost. TGP estimates it will support 4,760 to 9,820 average annual jobs across Mississippi, Alabama, and Georgia during construction, generating between $950 million and $2.4 billion in regional economic output.
To help reduce environmental and community impacts, approximately 28% of the proposed route will parallel existing infrastructure corridors, and several segments will be installed using horizontal directional drilling.
Mary Holcomb is the Digital Editor & Operations Manager at Gulf Energy Information, overseeing the Pipeline & Gas Journal, World Oil, and Underground Infrastructure brands. With over 5 years of experience, she drives digital content strategy and operations for these industry-leading publications.
Pipeline Gas Journal
oil-gas
12 July 20253 min read208-Mile Mississippi-To-Alabama Gas Pipeline Moves Into Ferc Review
Pipeline Gas Journal
12 July 2025
oil-gas
Adnoc Gas Enters $400M Lng Supply Agreement With SefeADNOC Gas has announced a three-year liquefied natural gas (LNG) supply agreement, worth approximately $400m, with Germany’s SEFE.
The contract will see ADNOC Gas deliver 0.7 million tonnes (mt) of LNG from its Das Island facility in Abu Dhabi, with deliveries commencing this year.
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The Das Island liquefaction plant, a key asset in ADNOC Gas’ portfolio, has a production capacity of six million tonnes per annum (mtpa).
Since its inception in 1977, the facility has dispatched more than 3,500 LNG cargoes across the globe, solidifying ADNOC Gas’ long-standing partnerships within the international energy sector.
ADNOC Gas CEO Fatema Al Nuaimi said: “This agreement marks a significant step in strengthening our long-standing partnership with SEFE and reinforces ADNOC Gas’ role as a reliable and responsible global energy provider, committed to supporting Germany’s energy security.
“It also reflects the strong progress we are making in delivering our strategic objectives and demonstrates the confidence our partners, investors, and stakeholders place in our ability to create long-term value in a dynamic energy landscape.”
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This supply agreement reinforces the strategic cooperation between the UAE and Germany, building on the 2022 Energy Security and Industry Accelerator (ESIA) pact and the 2024 Joint Declaration with the state of Baden-Württemberg.
Both initiatives are designed to promote energy security and the development of sustainable fuels.
SEFE chief commercial officer Frédéric Barnaud said: “Over the past two decades, we’ve built a strong partnership with ADNOC, and we value our relationship with such a reputable and reliable supplier.
“This new medium-term LNG contract builds on the long-term supply agreement with ADNOC that we signed last year, thereby adding another flexible source of LNG to our portfolio – to the benefit of both Europe’s security of supply and our global market trading activities.”
Last month, ADNOC Gas announced a final investment decision (FID) and awarded contracts worth $5bn for the first phase of its Rich Gas Development (RGD) project.
The project’s initial phase involves the expansion and optimisation of gas processing operations at four strategic locations: Asab, Buhasa, and Habshan onshore, as well as the Das Island offshore liquefaction facility.
Offshore Technology
oil-gas
11 July 20252 min readAdnoc Gas Enters $400M Lng Supply Agreement With Sefe
Offshore Technology
11 July 2025
oil-gas