oil-gas
06 May 2025
Gas Processing and LNGoil-gas
May 06, 2025Gas Processing and LNG
Indonesian state coal miner Bukit Asam is studying a plan to invest $3.1 B into a plant to convert coal into synthetic natural gas, its chief executive said on Monday.
It would be Bukit Asam's latest attempt to produce gas from coal, as the government pushes for domestic value addition on its natural resources, after its partner pulled out from a project to produce dymethyl ether gas.
Bukit Asam plans to convert 8.4 MM tonnes (t) of low-grade coal of around 3,700 kcal/kg GAR into 240 billion British thermal units (BBtu) per day (1.6 metric MMtpy), Arsal Ismail, chief executive of Bukit Asam told members of parliament.
"Some of Bukit Asam's low-grade coal reserves would be very suitable for conversion into synthetic gas," Arsal said, adding the project is aimed at meeting future gas demand in Indonesia.
The company plans to form a joint venture with state-controlled gas distributor Perusahaan Gas Negara (PGN) and a technology provider to build the plant, he said, without naming the technology provider.
Bukit Asam and PGN are currently conducting a feasibility study for the project, including the projected cost of the gas it will produce and its competitiveness against liquefied natural gas (LNG).
Arsal said an initial study indicated that the synthetic gas would be competitive against imported LNG. Indonesia is currently a net exporter of LNG, but some analysts expected that it could turn into a net importer by early 2040s.
Bukit Asam previously partnered with U.S. firm Air Products to convert coal into dimethyl ether, to produce substitution to liquefied petroleum gas (LPG) popularly used as cooking fuel.
Air Products, however, pulled out of the project in 2023 to redeploy its capital in other projects.
Bukit Asam is currently in talks with a number of Chinese companies for potential partnership to replace Air Products, Arsal said.
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Gascade Puts 400 Kilometers Of Hydrogen Core Network Into OperationGASCADE Gastransport GmbH (GASCADE) has reached a decisive milestone in building the German hydrogen network: about 400 kilometers of existing natural gas pipelines have been successfully converted to transport hydrogen. The initial filling of the first pipeline sections as part of the program Flow – making hydrogen happen establishes a North-South axis from the Baltic Sea region to Saxony-Anhalt, forming a central part of the German hydrogen core network. The hydrogen infrastructure is now available to the market and thus provides the basis for a successful hydrogen ramp-up.
This internationally unique project demonstrates how existing infrastructure can be quickly and cost-effectively transformed for hydrogen transport. GASCADE thereby creates planning security for the hydrogen ramp-up and makes a significant contribution to reducing CO₂ emissions in German industry. Managing Director Ulrich Benterbusch emphasizes the technical dimension and resulting opportunities: “With the successful conversion of 400 kilometers of pipeline, we reliably provide large-scale and central hydrogen infrastructure. Converting existing natural gas pipelines with a diameter of 1.4 meters to hydrogen is a technical pioneering achievement. This project is a strong signal for the German hydrogen economy and the industrial location of Eastern Germany.”
Managing Director Christoph von dem Bussche highlights the potential and the European perspective: Flow – making hydrogen happen is more than a technical project. It is a promise for the future. In 2025 we are creating the conditions to receive hydrogen from the European Baltic Sea region, international hydrogen imports via the port of Rostock, as well as green hydrogen produced on the Baltic coast – especially at the Lubmin site. From the get-go, we are considering the connection to our European neighbors. Because only together can we succeed in building a strong cross-border hydrogen economy.”
The now operational part of Flow – making hydrogen happen is the first step toward further core network connections to industrial hubs in southern Germany by 2029. As part of the program, additional pipelines to Poland, the Czech Republic, and also toward Bavaria and Austria will be converted or newly built. Additional information can be found at www.flow-hydrogen.com.
Pipeline Technology Journal
oil & gas
12 December 20252 min readGascade Puts 400 Kilometers Of Hydrogen Core Network Into Operation
Pipeline Technology Journal
12 December 2025
oil-gas
Pipeline Leak Spills 200,000 Litres Of Oil In German FarmlandEmergency crews have completed the cleanup of a pipeline leak that spilt at least 200,000 litres (about 53,000 gallons) of crude oil onto farmland in the state of Brandenburg, north of Berlin.
The leak in the pipeline, which transports oil from the Baltic Sea port of Rostock to the Schwedt refinery, occurred on Wednesday evening near the village of Gramzow during what officials described as a workplace accident.
A spokesman for regional emergency coordination confirmed that firefighters concluded their operation between 2 a.m. and 3 a.m. local time.
The Schwedt fire brigade reported that the oil initially shot several meters into the air from a small leak at a pumping station before settling on the adjacent agricultural land.
Refinery operator PCK said preliminary findings indicate the incident was caused by preparatory work for a scheduled safety test on the pipeline, ruling out any deliberate interference.
Alexander Trenn, head of the Schwedt fire brigade, told German news agency dpa that crews successfully removed all visible spillage. He noted that special suction vehicles and heavy machinery were used to collect the significant quantity of oil and contain its spread.
Roughly 100 firefighters and 25 PCK employees were involved in the overnight response, with PCK now responsible for handling the subsequent environmental remediation efforts.
Brandenburg’s environment minister, Hanka Mittelstädt, was expected to visit the site on Thursday to assess the extent of the damage to the affected countryside.
Pipeline Technology Journal
oil & gas
12 December 20252 min readPipeline Leak Spills 200,000 Litres Of Oil In German Farmland
Pipeline Technology Journal
12 December 2025
oil-gas
Iraq: Dno Charges Past 500 Million Barrels In Kurdistan And Picks Up SpeedDNO, the Norwegian oil and gas operator, has announced it is revving up operations in the Kurdistan region of Iraq as it charges past a major milestone marking 500 million barrels of oil produced from the Tawke license (DNO 75 percent and operator).
Drilling will restart at the flagship license next week following a two-and-a-half-year spending hiatus with the spud of a new production well targeting the shallow Jeribe reservoir in the Tawke field. Two rigs, the 'DQE-51' and the DNO-owned 'Sindy', have been mobilized to drill eight wells on the license through 2026 as the Company targets a 25 percent increase in gross operated production to 100,000 barrels of oil per day. The Tawke license contains the Tawke and Peshkabir fields, two of the region’s largest operated by an international oil company.
'Despite halting new drilling following the 2023 export pipeline closure and the drop in revenues, we are still pumping an impressive 80,000 barrels of oil per day with continuous, low-cost tweaks to the wells,' said Executive Chairman Bijan Mossavar-Rahmani. 'Given two decades of experience working these complex reservoirs, we have great confidence in our ability to extract much, much more oil from the fields in this license,' he said, adding, 'DNO holds the key to Tawke.'
The first Western company to enter Kurdistan in 2004, DNO kick-started a modern oil industry that has transformed the region’s economy. Along the way, the Company has catapulted into the ranks of the largest European-listed exploration and production companies with the successful reentry into its home surf offshore Norway where the Company is on track to exit 2025 with net production of 90,000 barrels of oil and gas equivalent. As in Kurdistan, DNO is now one of the most dynamic players on the Norwegian Continental Shelf, spearheading an industry campaign to 'get off the sofa' and significantly reduce time from discovery to production.
Original announcement link
Source: DNO
Energypedia News
oil & gas
12 December 20252 min readIraq: Dno Charges Past 500 Million Barrels In Kurdistan And Picks Up Speed
Energypedia News
12 December 2025
oil-gas
Us: Northern Oil And Gas Announces $1.2 Billion Joint Acquisition With Infinity Natural ResourcesHIGHLIGHTS
Northern Oil and Gas (NOG) has entered into a definitive agreement to acquire a 49% stake in Ohio Utica Shale Assets in partnership with Infinity for a purchase price, net to NOG, of $588.0 million in cash, subject to customary closing adjustments.
UPSTREAM ASSETS
The Acquired Assets are located in the Utica shale of eastern Ohio and include approximately 35,000 net acres with over 100 gross identified undeveloped locations.
The acquired upstream asset is one of the few remaining growth assets in the core of the Utica that can support a full rig development pace for multiple years. The upstream asset has an expected 2026 production, net to NOG, of ~65 MMcfe per day (2-stream, 92% gas) for 2026 with a 30%+ compound annual growth rate in production through the end of the decade, assuming a development plan with a continuous one rig program. The upstream asset represents a ~43% working interest net to NOG. In addition, the asset features a low PDP decline rate of ~15% in the next twelve months, falling to ~13% over the next several years. The asset is expected to generate ~$100MM in unhedged cash flow from operations net to NOG in 2026 at recent strip prices with ~19% generated by the midstream assets. The substantial growth expected on the assets on a go-forward basis is based on an average annual capital program of ~$100 million at a single rig cadence.
MIDSTREAM ASSETS
Captive midstream offers opportunity to drive best in class margins with limited incremental midstream growth-capital required. The midstream system has been built to accommodate a peak historical gross level of ~600 MMcfe per day. Significant midstream infrastructure with 140 miles of pipe supporting low- and high-pressure gathering, compression and 90 miles of water delivery systems. The Acquired Assets are positioned to realize improved pricing via direct connections to premium out of basin markets via the Tallgrass Rex pipeline.
The midstream system has ample capacity at regional processing plants (MPLX/Blue Racer) to grow future volumes and provides optionality across phase windows driven by both a rich and dry gas system. Midstream cash flows are expected to grow by 75% by 2028. NOG also believes that third party volume opportunities exist over time driving higher throughput and generating fee-based revenue, creating further upside.
Upon closing and transition of services, Infinity will be the operator of substantially all of the assets, with NOG participating in development pursuant to cooperation and multi-year joint development agreements entered into in connection with the acquisition.
The effective date for the transaction is July 1, 2025, and closing is expected by the end of the first quarter of 2026. Due to the effective date, NOG expects to receive a material downward closing purchase price adjustment. In connection with signing, NOG is placing a $58.8 million deposit in escrow. The obligations of the parties to complete the acquisition are subject to satisfaction or waiver of customary closing conditions.
MANAGEMENT COMMENTS
'NOG is singularly focused on executing transactions that add value to our platform for the long-term. We are extremely pleased to be partnering with Infinity on one of the last growth assets in the core of the Utica. The vertical integration of this asset adds an incremental dimension of value creation for shareholders and enhances resiliency with lower breakevens to generate free cash flow through cycle,' commented Nick O’Grady, NOG’s Chief Executive Officer. 'The Utica has emerged as one of the target rich natural gas plays in the United States. Infinity has already been a strong operating partner for NOG, and we share their focus on creating value. Our alignment in that vein sets the ground for a successful partnership, and we look forward to working together to achieve our mutual desire to generate returns for our respective investors. This transaction is now the largest we have done to date and is an excellent addition to our Appalachian portfolio, offering the benefit of an integrated midstream and a long-term, visible growth path well past the end of the decade.'
'This Utica transaction exemplifies the intersection where NOG shines – identifying and acquiring best in class assets with the potential for significant long-term upside while also providing valuable capital to like-minded operators seeking to expand their footprint,' commented Adam Dirlam, NOG’s President. 'These assets epitomize our returns-focused strategy: delivering immediately while offering significant growth potential further enhancing NOG’s optionality. Importantly, like our precedent joint development transactions, we have devised an aligned, conservative development and governance plan with a proven E&P company. We continue to be the partner of choice for our operators as the largest, best capitalized and most dependable non-op working interest owner in the United States.'
ADVISORS
Moelis & Company served as financial advisor to NOG for the acquisition.
Gibson, Dunn & Crutcher LLP is serving as legal counsel to NOG for the acquisition.
Original announcement link
Source: Norther Oil and Gas
Energypedia News
oil & gas
11 December 20255 min readUs: Northern Oil And Gas Announces $1.2 Billion Joint Acquisition With Infinity Natural Resources
Energypedia News
11 December 2025
oil-gas
Spe Warns Africa Needs $375 Billion To Scale Natural Gas DevelopmentAfrica will require an estimated $375 billion in investment over the next 10 to 12 years to fully develop its natural gas resources and meet rising domestic and export demand, according to the Society of Petroleum Engineers (SPE).
The estimate was presented by Dr. Riverson Oppong, Africa Director at SPE, during a workshop at the MSGBC Oil, Gas & Power 2025 conference in Senegal. Despite holding roughly 8% of global natural gas reserves, Africa remains underrepresented in global gas markets due to policy constraints, infrastructure gaps and limited access to financing, SPE said.
“Africa is a gas market,” Oppong said. “But despite our immense potential, we don’t participate meaningfully on the global stage. The constraints are policy, commercial frameworks, infrastructure and financing conditions.”
SPE noted that several countries are working to address these challenges through integrated gas master plans, improved contractual terms and stronger institutional capacity. However, large-scale upstream and midstream investment will be required to translate recent discoveries into sustained production growth.
According to industry data shared at the event, 17 high-impact exploration wells were completed across Africa in 2025, reinforcing expectations of continued upstream activity. SLB representatives said oil and natural gas demand on the continent is expected to increase by about 20% by 2050, driven by population growth, industrialization and power demand.
SLB highlighted digital technologies as a key lever for improving exploration success, drilling efficiency and production optimization across African assets. Technologies including IoT, advanced analytics and artificial intelligence were cited as tools to enhance real-time monitoring, predictive maintenance and operational decision-making.
“Data is a key focus area for improving the upstream value chain in Africa,” said Larry Velasco, Africa New Ventures Manager at SLB, noting that poor data quality can result in revenue losses of 15% to 25% for operators.
Paul Freeman, Global Exploration Advisor at SLB, added that rising energy demand underscores the urgency of new investment.
“Energy demand is increasing rapidly, and Africa’s oil and gas industry requires accelerated capital deployment to offset decline and meet peak demand,” Freeman said.
SPE said continued collaboration between operators, service companies, governments and financial institutions will be critical to unlocking Africa’s gas potential and advancing long-term energy security across the continent.
Image provided by APO Group on behalf of Energy Capital & Power.
World Oil
oil & gas
11 December 20252 min readSpe Warns Africa Needs $375 Billion To Scale Natural Gas Development
World Oil
11 December 2025
oil-gas
Ge Vernova Expects 80 Gw Of Gas Turbine Contracts By Year'S EndGE Vernova expects 80 gigawatts (GW) of signed combined-cycle gas turbine contracts by the end of the year as electricity demand from Big Tech's data centers ramps up, the manufacturer of power-generation equipment said on Tuesday.
As U.S. power demand reaches record highs due to the proliferation of energy-intensive data centers supporting artificial intelligence (AI) initiatives, demand for turbines and other equipment to produce electricity from natural gas has increased.
GE Vernova has sold out of its gas turbines through 2028 and has less than 10% left to sell the following year, CEO Scott Strazik said at a conference for investors.
On the prospect of AI-related investments developing into a bubble, Strazik said he didn’t see signs of any slowdown.
“What we’re seeing in the fourth quarter, and into 2026, is accelerating growth in demand,” he said. “Orders in the fourth quarter growing materially from hyperscalers.”
Going forward, data centers are expected to account for about a third of the Massachusetts-based company's gas-power transactions in the U.S., Strazik said.
So far this quarter, GE Vernova has signed 18 GW of gas power contracts, the company said, compared to 8 GW in the first three months of the year.
Some of the biggest obstacles include state and local permitting for power plants and the availability of fuel pipelines, which typically face problems being built across states.
Gas Processing and LNG
oil & gas
11 December 20252 min readGe Vernova Expects 80 Gw Of Gas Turbine Contracts By Year'S End
Gas Processing and LNG
11 December 2025
oil-gas
Nog Expands Utica Gas Portfolio In $1.2 Billion Deal With InfinityNorthern Oil & Gas Inc. (NOG) is expanding its Appalachian footprint with a $1.2 billion joint acquisition alongside Infinity Natural Resources, securing a 49% non-operated stake in a premier Utica shale upstream and midstream package previously held by Antero Resources and Antero Midstream. The deal delivers roughly 35,000 net acres, more than 100 undeveloped drilling locations, and a fully built gathering, compression and water-handling network positioned to support long-term growth.
The assets are expected to produce about 65 MMcfe/d net to NOG in 2026—92% gas—with a projected production CAGR above 30% through the decade as the partnership advances a single-rig development plan. NOG noted that the low-decline inventory and integrated midstream system underpin competitive breakevens below $2/MMBtu and support both margin expansion and cash-flow durability.
The midstream portfolio includes more than 140 miles of gathering lines, compression facilities and 90 miles of water infrastructure with capacity for significant throughput growth. NOG anticipates midstream free cash flow to rise more than 25% annually through the decade, supported by premium market access via the Tallgrass Rex pipeline.
Management said the transaction fits NOG’s strategy to build scale in high-quality gas basins while partnering with aligned operators. CEO Nick O’Grady called the Utica package “one of the last growth assets in the core of the play,” adding that the vertically integrated position enhances NOG’s resilience across commodity cycles.
The deal is expected to close by the end of Q1 2026, with an effective date of July 1, 2025. NOG plans to fund the acquisition through operating cash flow, available liquidity, and borrowings under its reserves-based lending facility.
World Oil
oil & gas
09 December 20252 min readNog Expands Utica Gas Portfolio In $1.2 Billion Deal With Infinity
World Oil
09 December 2025
oil-gas
Rystad Energy: Key Digital Initiatives Could Save Oil And Gas Industry Over Us$320 BillionDigital innovation is rapidly emerging as a defining force for the oilfield services (OFS) sector as it adapts to changing market conditions, creating opportunities for steady, long-term growth. Rystad Energy predicts that in the next five years, the oil and gas industry could save more than US$320 billion by further digitalising operations in five key areas: drilling optimisation, autonomous robotics, predictive maintenance, reservoir management, and logistics optimisation. The OFS business ecosystem is expected to undergo a significant transformation as continued merger and acquisition (M&A) activity, new business partnerships with technology firms, and greater software integration drive digital-first business strategies for key OFS players.
“We estimate that US$320 billion is a modest figure, as broader digital adoption across other business domains could generate even greater value. To realize this, executives will need to deliberately prioritise digital transformation by fostering a less risk-averse business culture,” said Binny Bagga, Senior Vice President, Supply Chain.
Learn more with Rystad Energy’s Service Market Solution.
The importance of digitalisation, although unstandardised and sometimes difficult to measure, is more often emerging in financial disclosures. Most of the market players in the supply chain do not yet break out standalone, generally accepted accounting principle (GAAP)-level ‘digital profit’ in the same way a pure software as a service company would. However, this has slowly started to change, with SLB now reporting a digital division in its earnings. SLB expects its digital division’s margin to reach 35% on a full-year basis in 2025. Another example is Viridien, a global technology and geoscience leader. Its digital, data and environment (DDE) segment generated US$787 million, growing 17% and delivering adjusted earnings before interest, taxes, depreciation and amortisation (EBITDA) of US$458 million last year. Digital revenue streams offer more stable, resilient growth trajectories that are less exposed to the volatility of upstream capex.
“The investment community is increasingly valuing energy-technology narratives, with service companies that clearly articulate technology-driven and recurring-revenue strategies often commanding higher valuation multiples than those tied solely to equipment cycles. However, such premium valuations hinge on demonstrated scalability. Emphasising digitalisation is a direct pathway to creating lasting shareholder value,” Bagga said.
Nevertheless, widespread adoption of digital oilfields faces significant barriers, including substantial upfront costs for hardware, software, ongoing maintenance and cybersecurity. These hurdles are especially acute for smaller firms or those operating with legacy infrastructure, complicating the justification of such investments amid economic uncertainty. To mitigate these challenges, mid-tier companies are selectively enhancing their offerings with targeted digital capabilities, while smaller niche players and specialised software vendors focus on delivering modular, custom solutions.
A notable trend in digital investment is the growing use of partnerships with technology firms, which complements internal capability building and acquisitions in the digital space. The overall intensity and frequency of these partnerships have increased sharply, especially since 2021, with the most significant uptick observed in the past two years among leading companies such as SLB, Halliburton, NOV and Baker Hughes. This pattern highlights a clear industry shift toward digital transformation, with large suppliers actively accelerating their collaborations with technology partners in recent years.
Oilfield Technology’s November/December 2025 issue
The November/December 2025 issue of Oilfield Technology focuses on how the upstream sector is modernising to stay efficient, competitive, and lower-carbon. It explores decarbonising drilling operations, improving performance through advanced monitoring and drilling technologies, reshoring and strengthening supply chains, enhancing offshore inspections, and tightening cybersecurity. Together, the articles highlight a sector pushing towards greater efficiency, resilience, and sustainability across the full lifecycle of oilfield operations.
Read the article online at: https://www.oilfieldtechnology.com/digital-oilfield/05122025/rystad-energy-key-digital-initiatives-could-save-oil-and-gas-industry-over-us320-billion/
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Oilfield Technology
oil & gas
06 December 20254 min readRystad Energy: Key Digital Initiatives Could Save Oil And Gas Industry Over Us$320 Billion
Oilfield Technology
06 December 2025
oil-gas
Digitalization May Unlock $320 Billion In Oil And Gas Savings By 2030, Analysts SayThe oil and gas industry could capture more than $320 billion in savings over the next five years by accelerating digital adoption across core operational domains, according to new analysis from Rystad Energy. The findings underscore how digital technologies—once considered optional enhancements—are rapidly becoming essential tools for efficiency, resilience and long-term competitiveness.
Rystad identifies five priority areas where digitalization can deliver the largest near-term gains: drilling optimization, autonomous robotics, predictive maintenance, reservoir management and logistics optimization. Together, these technologies could reshape cost structures for operators and oilfield service (OFS) companies as they contend with shifting market conditions and tighter capital discipline.
“We estimate that $320 billion is a modest figure,” said Binny Bagga, Senior Vice President, Supply Chain at Rystad Energy. “Broader digital adoption across additional business domains could generate even greater value. To realize this, executives will need to deliberately prioritize digital transformation by fostering a less risk-averse business culture.”
Digitalization’s growing influence is increasingly reflected in financial reporting across the OFS sector. While most service providers do not yet break out standalone digital revenue, that is beginning to change. SLB now reports results for its digital division, which is expected to reach a 35% margin in 2025. Technology and geoscience firm Viridien reported $787 million in digital, data, and environmental revenue last year, growing 17% with strong EBITDA performance.
According to Rystad, investors are rewarding companies that articulate credible, scalable digital strategies. Energy-technology narratives are commanding higher valuation multiples, but only when companies demonstrate that new platforms and software-based revenue streams can scale.
Still, digital transformation is not without challenges. High upfront hardware and software costs, cybersecurity requirements, and aging infrastructure continue to complicate adoption—particularly for smaller operators and service companies. To overcome these barriers, many mid-tier OFS firms are selectively adding digital capabilities, while niche players are offering modular software solutions tailored to specific operational needs.
A significant trend highlighted in the report is the accelerating pace of partnerships between OFS companies and external technology providers. Collaboration across oilfield engineering, automation, AI, cloud, and data-management firms has surged since 2021, driven heavily by SLB, Halliburton, NOV and Baker Hughes.
Rystad concludes that the OFS ecosystem is entering a new phase defined by digital-first business models, deeper technology integration, and a heightened focus on recurring revenue streams—marking a structural shift in how services will be delivered across the upstream value chain.
World Oil
oil & gas
06 December 20252 min readDigitalization May Unlock $320 Billion In Oil And Gas Savings By 2030, Analysts Say
World Oil
06 December 2025
oil-gas
Mauritania Accelerates Green Hydrogen Drive, Eyes 12.5M-Ton Output By 2035Mauritania is accelerating plans to become Africa’s premier green hydrogen producer, targeting 12.5 million tons by 2035. Backed by world-class solar and wind resources and proximity to Europe, the country is positioning itself as a competitive supplier for emerging global markets. A supportive regulatory framework – including Africa’s first dedicated Green Hydrogen Code and the creation of the Mauritanian Agency for Green Hydrogen – is helping attract large-scale foreign investment.
The country’s project pipeline has expanded rapidly in recent years, with multi-gigawatt developments led by global partners such as CWP Global, TotalEnergies, Chariot, GreenCo Energy, Masdar and Hynfra. International finance institutions, including the World Bank, European Investment Bank (EIB) and the EU, are providing technical and financial backing as Mauritania builds out regulatory systems, infrastructure and skills required to support the new industry.
Project Pipeline and Strategic Advantages
Mauritania holds the largest green hydrogen pipeline in sub-Saharan Africa. Flagship initiatives include CWP Global’s AMAN project, one of Africa’s most advanced developments, aiming for 30 GW of wind and solar capacity to produce up to 1.7 million tons of green hydrogen or 10 million tons of green ammonia annually. Chariot and TotalEnergies are advancing the 10 GW Project Nour near Nouadhibou, supported by a partnership with the Port of Rotterdam for future exports.
GreenCo Energy’s Megaton Moon is designed for 6 GW of electrolysis powered by a combined 13 GW of solar and wind, with Phase 1 expected in 2029. Additional projects include Hynfra’s $1.5-billion green ammonia facility scheduled for 2030 and a 10 GW green ammonia development by the Infinity Power-Masdar-Conjuncta consortium. The Mauritanian government views these investments as key to economic diversification, universal electrification and new industrial activity, including green steel and hydrogen-enabled mining.
Infrastructure, Workforce and Investment Requirements
Despite strong momentum, significant sector-wide challenges remain. Water scarcity is a critical constraint, requiring large-scale desalination – an energy-intensive process that will demand grid expansion. Planned upgrades include new wells, desalination plants in Nouadhibou and Ndiago, and a 1,400-km 225 kV transmission line from Néma to Nouakchott to link regional grids. A comprehensive World Bank assessment has also identified gaps in export infrastructure, including pipelines, storage terminals and port capacity.
Human capital readiness is another priority. The government notes a current lag in technical training, with the risk that Mauritania could be excluded from specialized jobs. The World Bank-backed Development of Energy Resources and Mineral Sector Support project will support vocational education, institutional strengthening and the country’s first utility-scale battery storage system to stabilize the grid.
To bridge financing and capacity gaps, Mauritania is working closely with Germany, France, Spain, the EU, the EIB and multilateral institutions under initiatives such as Global Gateway, which aims to mobilize €300 billion for green hydrogen in Mauritania. These partnerships aim to mobilize large-scale capital, de-risk private investment and support the regulatory clarity offered by the Green Hydrogen Code.
Mauritania’s green hydrogen ambitions will be spotlighted at the upcoming MSGBC Oil, Gas & Power 2025 conference and exhibition – taking place in Dakar from December 8-10. The hydrogen-focused session From Vision to Reality: How Will Hydrogen Shape Africa’s Landscape will examine how the region is moving from potential to execution, exploring green hydrogen’s broader economic impact across the MSGBC basin and positioning the resource as a cornerstone of West Africa’s energy and economic transition.
Explore opportunities, foster partnerships and stay at the forefront of the MSGBC region’s oil, gas and power sector. Visit www.msgbcoilgaspower.com to secure your participation at the MSGBC Oil, Gas & Power 2025 conference. To sponsor or participate as a delegate, please contact sales@energycapitalpower.com
Gulf Oil and Gas
oil & gas
06 December 20253 min readMauritania Accelerates Green Hydrogen Drive, Eyes 12.5M-Ton Output By 2035
Gulf Oil and Gas
06 December 2025
oil-gas
Egypt'S Petrojet Secures $273M Oman Gas Pipeline Deal, Deepening Energy TiesEgypt's Petroleum Projects and Technical Consultations Company (PETROJET) has secured a $273 million Engineering, Procurement, and Construction (EPC) contract to build a 193-kilometer natural gas pipeline in Oman.
The contract, announced on Monday during a meeting between Egyptian Minister of Petroleum and Mineral Resources Karim Badawi and OQ Gas Networks (OQGN) Managing Director Mansoor Ali Al-Abdali, highlights the growing energy infrastructure cooperation between the two nations.
In addition to the gas pipeline, PETROJET will implement the first phase of OQGN's planned hydrogen pipeline network, undertaking 400 kilometers of the total 2,000-kilometer project at an estimated cost of $250 million.
The Egyptian firm is also preparing to compete for upcoming green hydrogen and Natural Gas Liquids Extraction (NGLE) projects, leveraging its international expertise. The announcement was made at Oman’s Green Hydrogen Summit, where leaders discussed collaborative opportunities.
Separately, Minister Badawi and Mohsen Al-Hadhrami, Undersecretary of the Ministry of Energy and Minerals and Chairman of Petroleum Development Oman (PDO), reviewed PETROJET’s involvement in civil works and housing under a new framework agreement, alongside five other firms.
Other Egyptian firms, Engineering for the Petroleum and Process Industries (ENPPI) and Egypt Gas, are moving forward with registration on OQGN’s Tawreed platform. Both companies are finalizing technical pre-qualification documents for gas pressure reduction stations at Duqm Refinery, aiming for completion before the end of the year.
ENPPI, a current partner with OQGN, Oman Tank Terminal Company (OTTCO), and Duqm Refinery, is listed as a strong contender for all forthcoming project tenders.
Further discussions, including meetings with OQ Alternative Energy and Hydrogen Oman Company (Hydrome), focused on expanding Egyptian companies’ footprint in oil, natural gas, green hydrogen, and ammonia projects, particularly in the key regions of Salalah and Duqm.
The suite of agreements solidifies the deepening relationship between the Egyptian and Omani energy sectors, with PETROJET, ENPPI, and other Egyptian firms poised for pivotal roles in Oman’s emerging energy and industrial development initiatives.
Pipeline Technology Journal
oil & gas
03 December 20252 min readEgypt'S Petrojet Secures $273M Oman Gas Pipeline Deal, Deepening Energy Ties
Pipeline Technology Journal
03 December 2025
oil-gas
Petrobras Trims $109 Billion Capex Plan As Lower Oil Prices Pressure Dividends(Bloomberg) – Brazilian oil major Petrobras announced a 2% decrease in its next five-year investment plan to $109 billion, putting dividend payments in doubt at a time of lower oil prices. Shares fell.
The state-controlled oil producer is caught between the government’s desire to grow the economy - especially ahead of a 2026 presidential election - and investors who demand high dividends and low debt. While Petrobras announced a regular dividend payout of at least $45 billion for the 2026-2030 period, similar to the previous plan, it didn’t commit to pay any extraordinary payouts to shareholders.
Petrobras shares slid as much as 3.4% in Sao Paulo on Friday, the largest intraday drop since August, while Brent prices were are slightly lower.
“The absence of short-term capex optimization could result in single-digit dividend yields ,” Itau Unibanco Holding SA said in a note to clients. “This could be perceived as disappointing by investors.”
Petroleo Brasileiro SA, as it is formally known, will direct $91 billion of the total capital expenditure to projects under implementation, of which $10 billion will still need budget confirmation subject to a financing analysis. The rest is still under analysis “with a lower degree of maturity,” it said in a filing on Thursday.
The spending plan is being closely watched by investors as it has an important political dimension in Brazil. The company is a major source of cash for the federal budget. It is the first time Petrobras has reduced its five-year budget after President Luiz Inacio Lula da Silva took office in 2023.
The previous plan was based on an oil price assumption of $83 a barrel, while Brent crude is currently trading near $63.
Petrobras earmarked 71.6% of the 2026-2030 plan, or $78 billion, for exploration and production. That includes boosting output at its deep-water fields in the so-called pre-salt region, while also exploring new areas in Brazil and abroad.
The Rio de Janeiro-based company’s plan includes eight new offshore production units by 2030, and an additional 10 production vessels that are being considered for after 2030. It expects to drill 15 wells at Brazil’s Equatorial Margin — an offshore region where it recently got a permit for its first well — and is hoping to find discoveries similar to the ones Exxon Mobil Corp. has made off the coast of Guyana.
Oil production
Oil production is expected to peak at 2.7 million barrels a day by 2028, up from a previous plan ceiling. Petrobras also raised the short-term target to 2.5 million barrels of oil a day next year from the previous 2.4 million, potentially adding to a global glut at a time when the International Energy Agency is concerned about oversupply.
Refining and related business lines such as fertilizers and logistics will account for about $20 billion of spending over the next five years. Petrobras is developing a portfolio of renewable fuels in an effort to decarbonize industries including shipping and aviation. The company said it will not build new refineries.
Planned spending on gas and low-carbon projects is at $4 billion, driven by biofuels, biomethane and a return to ethanol production. Petrobras is looking at taking preferably strategic minority partnerships or shared control with relevant players in these areas, it said.
Petrobras kept its debt ceiling at $75 billion.
The plan “could make investors more skeptical toward the Petrobras investment thesis, as it shows a tight financial situation amid lower Brent prices, despite solid operating performance,” BTG analyst Gustavo Cunha wrote in a report, noting that Petrobras’s outlook now depends even more on a decline in Brazil’s sovereign risk heading into the 2026 elections.
World Oil
oil & gas
29 November 20254 min readPetrobras Trims $109 Billion Capex Plan As Lower Oil Prices Pressure Dividends
World Oil
29 November 2025
oil-gas