oil-gas
19 September 2025
Energypedia Newsoil-gas
Sep 19, 2025Energypedia News
Iberdrola has reached an agreement to sell 100% of the shares of Iberdrola Renovables Magyarország KFT, which owns its business in Hungary, to a consortium formed by Premier Energy—who previously acquired the company’s assets in Romania in 2024—and to the Hungarian group iG TECH CC. Through this transaction, the Group will receive €171.2 million for the shares of the company and a dividend distributed prior to closing.
The assets sold include 158 megawatts (MW) of operational wind capacity, commissioned by Iberdrola since entering the country in 2008. These assets will shortly be selling their energy in the wholesale market, once the regulatory 15-year tariff period ends. Currently, 124 MW are already operating in the free market, and the remaining 34 MW will do so in less than a year. The transaction is subject to ordinary regulatory approvals.
This deal is part of Iberdrola’s strategy to focus its investments on key businesses and markets, mainly in networks in the United States and the United Kingdom, and in regulated or long-term contracted generation, where income stability and predictability are maximized.
It is also fully in line with the concentration of activities of Iberdrola Energía Internacional to focus on core EU markets and in Australia.
During 2025, Iberdrola has announced several long-term strategic alliances and asset rotation transactions. These include the recent agreement for the sale of its businesses in Mexico, and its partnership with Masdar to co-invest €5.2 billion in the 1.4 GW East Anglia THREE offshore wind farm in the United Kingdom.
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Source: Iberdrola
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Egypt Pays $500M In Arrears To Foreign Oil CompaniesEgypt’s government has paid nearly $500 million in overdue debt to foreign companies in a bid to encourage them to intensify operations and reverse a decline in its gas output.
The government made the payment in September and intends to settle another part of the arrears with a payment of $620 million before the end of 2025, the Saudi news website Asharq Business said, quoting an unnamed Egyptian official.
With this month’s settlement, Egypt owes foreign oil companies operating its oil and gas fields around $1.72 billion, the report said.
It added that the official affirmed the government hoped to “clear all the overdue dues” to foreign oil companies by the end of the first quarter of 2026.
Earlier this month Egypt’s oil minister Karim Badawi said that gas production is expected to recover following significant discoveries by companies operating in Egypt.
Badawi, speaking at a meeting with heads of those companies in Cairo, said the decision by President Abdel Fattah Al-Sisi to pay foreign partners regularly would boost investor confidence and encourage them to pump more investments.
“The joint efforts with our partners in the oil and gas sector have contributed to reducing the decline in gas production, achieving stability and beginning the journey back to high production rates,” the minister said.
Prime Minister Mostafa Madbouly said in July that new projects and the award of more contracts to foreign oil majors would boost Egypt’s gas output and allow it to export again in 2027.
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Arabian Gulf Business Insight
oil & gas
23 September 20252 min readEgypt Pays $500M In Arrears To Foreign Oil Companies
Arabian Gulf Business Insight
23 September 2025
oil-gas
Every Last Drop: Ai-Powered Analysis Reveals Oil Industry'S Trillion-Barrel Opportunity In Existing FieldsThe oil industry possesses a trillion-barrel opportunity within existing fields that could meet global demand through 2050 without major new discoveries, according to groundbreaking analysis from Wood Mackenzie.
"The oil industry's challenge is enormous," said Andrew Latham, SVP Energy Research at Wood Mackenzie. "Total liquids demand under our base-case Energy Transition Outlook scenario is just less than 1 trillion bbls through 2050. Without upgrades to current development plans, today's onstream fields are set to fall short by almost 300 billion bbls. This deficit would grow by another 50 billion bbls under our delayed transition scenario."
Wood Mackenzie’s proprietary Synoptic AI-powered analysis of oilfield performance shows existing fields are far from exhausted. The new AI-powered Analogues feature enables efficient, unbiased assessment of Wood Mackenzie’s already industry-leading data to deliver previously overlooked insights into recovery upside.
In one of the first deployments of the Analogues feature, it was revealed that better recovery from producing fields could yield an additional 470 billion to over 1000 billion bbls. This potential only requires the application of established best practices already deployed successfully across the industry, not unproven technologies.
National oil companies control almost 70% of recovery upside
Using proprietary data on reservoir geology, hydrocarbon quality, in-place resources, operator access to finance and technology, costs and fiscal terms, Wood Mackenzie estimates upside oil recovery factors. The analysis examined over 30 000 fields worldwide using machine learning to identify similar analogues across 60+ parameters.
The research reveals that national oil companies (NOCs) and state-controlled enterprises operate fields containing more than 320 billion bbls of upside potential if top-quartile recovery factor is achieved and 700 billion barrels on a best-in-class recovery basis - representing almost 70% of the global opportunity.
Iran, Venezuela, Iraq, and Russia stand out with the largest recovery upside potential of any countries. By contrast, major international oil companies, despite operating above-average quality fields, control just 6% of global upside potential due to their already strong performance levels.
"The future of oil supply will be increasingly onshore and NOC-operated," adds Latham. "While Majors have demonstrated superior recovery factors, they've become victims of their success with limited remaining portfolio upside."
Technology partnerships essential for unlocking reserves
The analysis reveals a critical mismatch between opportunity locations and expertise. NOCs currently achieve recovery factors slightly below the industry average of 29%, despite operating fields with geological potential for best-in-class performance of 39%. This performance gap creates substantial opportunities for international oil companies and service providers to forge deeper partnerships with state enterprises.
Success depends on NOCs improving technology and capital access whilst offering attractive commercial terms to international partners. More opportunities exist in producing fields than available capital. Host governments seeking optimal resource development need attractive terms to secure the best operators. This dynamic positions well-capitalised international players to capture significant value through strategic partnerships.
AI transforms analysis of oil field upside potential
By analysing reservoir lithology, porosity, oil gravity, viscosity, fiscal terms and development costs, Wood Mackenzie's AI-powered Analogues feature ranks each field's closest analogues using machine learning similarity scores
This approach identifies four reserve scenarios for over 2500 conventional oil fields. These range from most likely reserves under current plans to best-in-class potential based on top-performing analogues. The unbiased methodology ensures lessons derive from truly similar fields rather than superficial matches.
Upside potential lies almost exclusively within onshore and shallow offshore fields, accounting for 63% and 31% of best-in-class opportunities, respectively. Deepwater fields, typically operated by well-funded companies with excellent technological access, hold less than 6% of remaining upside.
Meeting demand without new oil field discoveries
The findings challenge conventional wisdom about major new oil discoveries. Since the 1980s, the industry has met growing demand primarily through upward revisions to existing fields rather than new finds. The discovery-production gap has widened each decade.
Exploration will continue to add value by finding advantaged resources to displace higher-cost or otherwise disadvantaged barrels. However, new discoveries alone cannot come close to bridging a gap of this size.
While the industry maintains nearly 2 trillion bbls in undeveloped greenfield resources, barely 10% appears commercially viable under current conditions. Most resources will remain stranded due to challenging economics or technical constraints.
"Security of supply need not depend on unpredictable exploration results or unproven technologies," the analysis concludes. "Existing fields and proven recovery methods can meet the challenge with the right partnerships and investment approaches."
Achieving top-quartile performance industry-wide would boost average recovery factors from 29% to 34%, adding 470 billion bbls of reserves and fundamentally reshaping global energy security prospects.
"Improved recovery factors will be essential to meeting future demand for oil as there are unlikely to be anywhere near enough new fields to offset the natural decline of existing supply," concludes Latham. "Using AI to help understand the potential of existing fields and gauge how much the world will need new fields in future represents a significant advance from traditional field analogue methods based on filtering that produce biased results."
Read the article online at: https://www.oilfieldtechnology.com/digital-oilfield/18092025/every-last-drop-ai-powered-analysis-reveals-oil-industrys-trillion-barrel-opportunity-in-existing-fields/
IMI delivers ‘largest production’ choke valves to landmark North Sea unmanned production platform.
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Oilfield Technology
oil & gas
18 September 20255 min readEvery Last Drop: Ai-Powered Analysis Reveals Oil Industry'S Trillion-Barrel Opportunity In Existing Fields
Oilfield Technology
18 September 2025
oil-gas
Dp World’S Cad $150 Million Investment Expands Canada’S Canola Oil Export CapacityDP World has begun full operations at its new Canola Oil Transload Facility at Fraser Surrey, a CAD $150 million strategic investment that enhances Canada’s export capacity and strengthens direct connectivity between prairie farmers and international markets.
In 2024, Canada exported 3.5 million metric tonnes of canola oil, valued at CAD $5.9 billion. With production concentrated in Saskatchewan (55%), Alberta (29%), and Manitoba (16%), efficient rail-to-port infrastructure is vital to maintaining global competitiveness.
The new Fraser Surrey facility adds 1 million metric tonnes a year of capacity, streamlining the movement of canola oil from rail to vessel. Oil arrives by rail from the prairies, is stored in three large-capacity tanks, and is pumped directly to ships via a dedicated underground pipeline.
Doug Smith, CEO of DP World in Canada, said: “By streamlining the movement of oil from rail to vessel, this facility reduces handling, increases throughput, and improves reliability, providing Canadian producers with faster, more efficient access to global markets. The entire operation is designed to support the growing worldwide demand for Canadian canola oil — an essential ingredient in food, fuel, and renewable products.”
Honourable Ravi Kahlon, Minister of Jobs and Economic Growth, Government of BC, said: “The completion of this new canola oil facility at Fraser Surrey highlights British Columbia's critical role as a catalyst for Canada's new economy. With our ports connecting Canada's heartland to the world, we're supporting farmers and exporters across Western Canada and creating good jobs here in B.C. while driving sustainable economic growth for the province as we face the threat of tariffs.”
Tom Hamilton, Executive Vice-President of Agribusiness Operations, Richardson International, said: “DP World’s new facility strengthens our ability to compete in global markets by enhancing both canola oil capacity and supply chain reliability. This investment streamlines the critical connection between prairie production and coastal shipping, allowing Richardson to respond to growing customer demand even further and deliver Canadian canola oil more efficiently to buyers around the world.”
The new canola facility complements DP World’s existing expertise in bulk and breakbulk handling at Fraser Surrey, where it manages a wide range of agricultural and industrial commodities including grain and steel. By expanding capacity for one of Canada’s most important agricultural exports, DP World is reinforcing its role as a leader in bulk trade infrastructure, supporting global food security and renewable fuel markets.
The launch of the new canola facility follows DP World’s recent joint development agreement with the Montreal Port Authority to design the future Contrecœur container terminal. Together, these projects underscore DP World’s long-term commitment to strengthening Canada’s trade infrastructure from coast to coast.
Canola Oil Facility Features
Rail access: Two spur tracks for unloading, railcar offloading stations, pumps, and piping.
Storage: Three 15,000-metric-tonne capacity steel tanks (18 metres high, 37 metres in diameter), including containment walls for environmental protection.
Pipeline: Underground transmission and recycle line connecting the storage tanks directly to the marine trestle.
Marine access: New trestle and vessel loading platform with a marine loading arm and upgraded berthing safety features.
Supporting infrastructure: Control building, motor control centre and lighting.
Construction began in late 2023 and was completed on schedule. The facility highlights DP World’s commitment to building sustainable, strategically located trade infrastructure that strengthens Canada’s agricultural economy, and ensures more resilient global supply chains in a challenging global environment.
With operations now underway, DP World is helping Canadian producers expand their access to international markets, creating long-term value for customers and communities across the country.
Gulf Oil and Gas
oil & gas
18 September 20253 min readDp World’S Cad $150 Million Investment Expands Canada’S Canola Oil Export Capacity
Gulf Oil and Gas
18 September 2025
oil-gas
Ukraine Will Need To Buy $1 B Of Gas To Hit Winter Storage Target After Russian AttacksUkraine has secured gas reserves to meet 80%–90% of its winter demand and needs up to $1 B of additional fuel to get through its fourth heating season since Russia invaded the country, industry officials and analysts say.
Russia has spent the past two years attacking Ukrainian energy infrastructure to weaken its military and undermine civilian morale. The campaign has reduced domestic gas production and power generation dramatically, with Russian strikes continuing almost daily.
Ukraine has about 11 Bm3 of gas in storage, amounting to more than 80% of the government’s 13.2 Bm3 target, said Yurii Boiko, a supervisory board member at state-owned power grid operator Ukrenergo.
Ukrainian energy consultancy ExPro, however, put stocks at 12 Bm3, or 90% of target.
Targets may need to be revised. That means 1 Bm3–2 Bm3 will have to come from domestic production or be imported from other European countries, officials and analysts said. That would cost the country between $500 MM and $1 B, according to calculations based on current and last winter's EU gas price.
Officials warn that further attacks on production or storage sites could force Ukraine to revise its targets. Last winter, blackouts lasted up to 18 hours a day in some areas.
"If gas infrastructure is damaged, we will have to look for costly resources to make up for the shortfall," Boiko said.
Ukraine stored 12.8 Bm3 of gas ahead of last winter, which proved too little after Russian attacks damaged infrastructure, said Serhiy Makogon, former head of the Ukrainian gas transmission system.
"It brought the country to the brink of a gas blackout," Makogon said. He estimates remaining gas import needs for the season at 1 Bm3 to 1.5 Bm3, costing up to about $900 MM.
Russian attacks cut Ukraine's gas output by about 0.5 Bm3 last winter, said Oleksandr Kharchenko, director of the Kyiv-based Centre of Energy Studies. He said he would like to see gas stocks at 14 Bm3 for winter.
Polish gas shipments on the rise. Before the war, Ukraine produced about 55 MMm3d of gas, or up to 20 Bm3y. Current production figures are classified.
Ukraine mainly imports gas from Hungary, but shipments via Poland have been on the rise. Existing interconnectors allow Ukraine to import more than 60 MMm3d - more than enough to cover daily demand in case of an acute need.
Poland is working on doubling capacity on its link with Ukraine to 4 Bm3y by early 2026 (learn more). Ukraine also plans to import U.S. liquefied natural gas (LNG) via Germany, Greece, Lithuania and Poland.
Importing gas is becoming safer than stockpiling, given Russian attacks on production and storage facilities, said Andriy Kobolev, former CEO of state-run Naftogaz.
Ukraine has Europe's largest underground storage facilities, with capacity of 30 Bm3. Western companies stored up to 3 Bm3 of gas in Ukraine last year, but volumes fell to zero this year after Russian attacks intensified.
Gas Processing and LNG
oil & gas
17 September 20253 min readUkraine Will Need To Buy $1 B Of Gas To Hit Winter Storage Target After Russian Attacks
Gas Processing and LNG
17 September 2025
oil-gas
Energean Wins Us$4 Billion In Israeli Gas Contracts In H1 2025The move has bolstered the company’s contract pipeline to US$20 billion (£14.77 billion) over the next 20 years.
Energean, a gas producer, secured US$4 billion worth of new long-term Israeli gas offtake contracts in the first half of 2025 (H1 2025), ended 30 June.
This strategic move has significantly bolstered the company’s contract pipeline to US$20 billion over the next two decades.
Despite this positive development, Energean’s financial performance in the first half of the year has been affected by a series of operational challenges including a planned shutdown for essential works and a government-mandated suspension of production.
The company's operations across Egypt, Italy, Croatia, the UK and Greece, which collectively produced 44 000 boe/d in H1 2025, remain a focus for maximising value.
However, Energean reported an 11% decline in core profit for the six months leading up to 30 June, while its after-tax profit increased by nearly 24%.
Adjusted earnings before interest, taxes, depreciation, amortisation and exploration expense (EBITDAX) stood at US$505 million, with after-tax profit reaching US$110 million.
The temporary suspension of production in Israel in June and a delay in commissioning the second oil train have led Energean to revise its production forecast for the year.
The company now expects production to range between 145 000 boe/d and 155 000 boe/d, a decrease from the previously anticipated 155 000 boe/d to 165 000 boe/d.
In Egypt, Energean's CEO, Mathios Rigas, told Reuters there is an estimated further 3 trillion ft3 of gas beneath its existing platforms.
Offshore Israel, the company is considering drilling into untapped formations in deep Mesozoic rocks in Block 23, which Rigas believes could be a "new play opener for the whole East (Mediterranean)".
However, Energean is seeking a partner for this well and anticipates that drilling will have to wait for regional stability.
Rigas also mentioned that Energean expects to produce up to 2 billion m3 a year from its Katlan field off Israel, which is set to begin production in 2027.
This output is due to be transported via the proposed Nitzana pipeline from Israel to Egypt, which is yet to be constructed.
Read the article online at: https://www.oilfieldtechnology.com/drilling-and-production/15092025/energean-wins-us4-billion-in-israeli-gas-contracts-in-h1-2025/
The deal encompasses a comprehensive range of OCTG supplies including pipes and VAM premium connections.
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Oilfield Technology
oil & gas
15 September 20252 min readEnergean Wins Us$4 Billion In Israeli Gas Contracts In H1 2025
Oilfield Technology
15 September 2025
oil-gas
Crc To Acquire Berry In $717 Million All-Stock Merger, Expanding California Oil AssetsCalifornia Resources Corporation (CRC) will acquire Berry Corporation in an all-stock transaction valued at about $717 million, including Berry’s net debt, the companies announced on Sept. 15.
Under the agreement, Berry shareholders will receive 0.0718 shares of CRC stock for each Berry share, representing a 15% premium based on Sept. 12 closing prices. Once completed, CRC shareholders will own roughly 94% of the combined company. The transaction has been unanimously approved by both boards and is expected to close in the first quarter of 2026, pending regulatory and shareholder approvals.
CRC President and CEO Francisco Leon said the combination will strengthen the company’s California-focused portfolio. “The combination of CRC and Berry will create a stronger, more efficient California energy leader. This transaction is attractively valued and immediately accretive across key financial metrics, strengthening our ability to deliver sustainable value to shareholders,” Leon said.
Berry Chair Renée Hornbaker called the merger a timely opportunity: “The industrial logic of this merger will allow Berry shareholders to benefit from the creation of a larger and more sustainable business, with an improved capital structure and significant operational synergies.”
The combined company would have produced about 161,000 barrels of oil equivalent per day in the second quarter of 2025, with 87% of reserves already developed. CRC said it expects to generate $80–90 million in annual synergies within a year of closing and maintain a leverage ratio below 1.0x.
The merger also gives CRC access to Berry’s Uinta Basin acreage in Utah, providing what the companies described as additional operational and financial optionality. CRC will assume Berry’s debt and may refinance it through existing cash and credit lines.
World Oil
oil & gas
15 September 20252 min readCrc To Acquire Berry In $717 Million All-Stock Merger, Expanding California Oil Assets
World Oil
15 September 2025
oil-gas
Us: Epa Releases Proposal To End The Costly Greenhouse Gas Reporting Program, Saving Up To $2.4 BillionIn accordance with President Trump’s Day One executive orders, U.S. Environmental Protection Agency (EPA) Administrator Lee Zeldin has announced a proposed rule to end the burdensome Greenhouse Gas Reporting Program (GHGRP), saving American businesses up to $2.4 billion in regulatory costs while maintaining the agency’s statutory obligations under the Clean Air Act (CAA). Unlike other mandatory information collections under the CAA, the GHGRP is not directly related to a potential regulation and has no material impact on improving human health and the environment. If finalized, the proposal would remove reporting obligations for most large facilities, all fuel and industrial gas suppliers, and CO2 injection sites.
'Alongside President Trump, EPA continues to live up to the promise of unleashing energy dominance that powers the American Dream. The Greenhouse Gas Reporting Program is nothing more than bureaucratic red tape that does nothing to improve air quality,' said EPA Administrator Zeldin. “Instead, it costs American businesses and manufacturing billions of dollars, driving up the cost of living, jeopardizing our nation’s prosperity and hurting American communities. With this proposal, we show once again that fulfilling EPA’s statutory obligations and Powering the Great American Comeback is not a binary choice.'
By reducing the overall regulatory burden, current regulated parties will be able to focus compliance expenditures on actual, tangible environmental benefits. As the agency continues to Power the Great American Comeback, this proposal represents a significant step toward streamlining operations, cutting unnecessary red tape, unleashing American energy, and advancing EPA’s core mission of protecting human health and the environment.
The GHGRP requires 47 source categories, covering over 8,000 facilities and suppliers in the U.S. to calculate and submit their greenhouse gas (GHG) emissions reporting annually. Following a careful review, EPA proposed that there is no requirement under CAA section 114(a) to collect GHG emission information from businesses nor is continuing the ongoing costly data collection useful to fulfill any of the agency’s statutory obligations. Therefore, EPA is proposing to remove all GHG reporting requirements, except for those subject to the Waste Emissions Charge (WEC).
CAA section 136 only requires data collection for segments of subpart W (petroleum and natural gas systems) subject to the WEC. On July 4, 2025, President Trump signed the One Big Beautiful Bill Act, which amended CAA section 136(g), so that the WEC now applies to emissions reported for calendar year 2034 and for each year thereafter. In accordance with the law, EPA will not be collecting subpart W data until 2034.
EPA will initiate a public comment period to solicit input. Further information on the public comment process and instructions for participation will be published in the Federal Register and on the EPA website.
For more information on the proposed rule and how to comment, please see EPA’s fact sheet here.
Background
On March 12, 2025, Administrator Zeldin announced that the agency was reconsidering the GHGRP. This was announced in conjunction with a number of historic actions to advance President Trump’s Day One executive orders and Power the Great American Comeback. While accomplishing EPA’s core mission of protecting human health and the environment, the agency is committed to fulfilling President Trump’s promise to unleash American energy.
Congress authorized funding for the creation of the GHGRP in the Fiscal Year 2008 Consolidated Appropriations Act. The Obama EPA promulgated the program and began collecting data in 2010. The GHGRP currently requires reporting of GHG data from certain large GHG emission sources, fuel and industrial gas suppliers, and CO2 injection sites.
November 18, 2024, the Biden EPA issued the final WEC rule to implement the 2022 Inflation Reduction Act’s methane tax provisions. Congress amended the CAA by adding section 136, “Methane Emissions and Waste Reduction Incentive Program for Petroleum and Natural Gas Systems.” Among other things, CAA section 136 (c)-(g) required EPA to impose and collect a waste emission charge on methane emissions that exceeded specified thresholds from applicable facilities that reported more than 25,000 metric tons of carbon dioxide equivalent (MTCO2e) of GHGs under the petroleum and natural gas systems subpart W source category.
On March 14, 2025, President Trump signed a joint resolution of disapproval under the Congressional Review Act, disapproving the November 2024 final WEC rule.
Original announcement link
Source: EPA
Energypedia News
oil & gas
13 September 20254 min readUs: Epa Releases Proposal To End The Costly Greenhouse Gas Reporting Program, Saving Up To $2.4 Billion
Energypedia News
13 September 2025
oil-gas
Kuwait Petroleum Eyes $7 Billion Pipeline Deal To Fund Upstream Oil Expansion(Bloomberg) - Kuwait Petroleum Corp. (KPC) is weighing a multibillion-dollar pipeline lease deal that could raise as much as $7 billion to support its ambitious upstream oil investment program. The state-backed company, OPEC’s fifth-largest producer, is considering leasing 13 pipelines for up to 25 years, according to people familiar with the matter. Centerview Partners LLC is advising on the potential transaction.
The deal would mirror recent monetization strategies by regional peers Saudi Aramco and Abu Dhabi National Oil Co. (ADNOC), which have leased key midstream assets to global investors to free up capital for upstream growth. KPC plans to invest $65 billion across its portfolio, with about $33 billion earmarked for boosting oil production capacity toward its long-term goal of 4 million barrels per day by 2035.
CEO Sheikh Nawaf Al-Sabah has signaled flexibility in funding strategies, pointing to pipeline monetization as a competitive option. “If it comes from a pipeline deal, which would be open to both domestic and foreign investors, I’ll pursue that,” he said in an earlier interview.
The company’s upstream investment push comes amid growing demand for Gulf crude and heightened competition for capital in the global energy transition. Any final decision will require government approval, but a pipeline deal would underscore Kuwait’s commitment to sustaining and expanding upstream output in line with its OPEC role.
The deliberations follow recent major regional infrastructure transactions, including BlackRock’s $11 billion lease-and-leaseback deal with Aramco on the Jafurah gas project, as well as prior pipeline divestments by ADNOC. By pursuing similar partnerships, KPC is positioning itself to unlock capital while accelerating upstream drilling and production projects critical to its long-term energy strategy.
World Oil
oil & gas
12 September 20252 min readKuwait Petroleum Eyes $7 Billion Pipeline Deal To Fund Upstream Oil Expansion
World Oil
12 September 2025
oil-gas
Kuwait Soil Remediation Program Accelerates With Eight Million Tonnes TreatedRestoration continues to progress in the world’s biggest anthropogenic oil spill in Kuwait as over 8 million tonnes of soil have been cleaned through washing and bioremediation as part of KAK-LAMOR JV/C’s clean-up efforts.
Over a decade ago, the Kuwait Environmental Remediation Program (KERP) was established by the United Nations Compensation Commission (UNCC), Kuwait National Focal Point (KNFP) and Kuwait Oil Company (KOC) to address the extensive damage resulting from the Gulf War.
The conflict left Kuwait’s landscape heavily contaminated with oil, including wet and dry oil lakes, contaminated soil, and sludge. Following the destruction of some 700 oil wells in the early 1990s, approximately 26,000,000m3 of soil was contaminated with crude oil, signalling the launch of one of the most extensive remediation programmes involving the cooperation and expertise of a consortium of international partners.
In Kuwait, three billion dollars of funding from the UNCC is contributing towards the clean-up of 300km2 with about 26 million cubic meters of oil-contaminated soil.
Part of this remediation work is managed by KAK-LAMOR JV/C, a joint venture between Kuwaiti EPC contractors Khaled Ali Al-Kharafi & Brothers Co. and Finnish remediation specialists Lamor.
KAK-LAMOR JV/C are undertaking two remediation projects, one in northern Kuwait, and another in southern Kuwait. These two projects account for approximately one quarter of the 300km2 contaminated area.
CDE, a leader in wet processing solutions, was appointed by KAK-LAMOR JV/C to supply two soil washing plants to support soil remediation efforts, one each in north and south Kuwait, in conjunction with its local partner Gulf Center United Industrial Equipment Co.
Construction of the soil washing plants started in 2023, with the facility in the north operating later that year, and the southern facility operational from early 2024. Both of these plants range from 50-100 tonnes per hour (tph) depending on the fines content of the feed material.
As the material is very diverse and has varying age particle size distribution (PSD), both soil washing and bioremediation are being used in this project, both of which complement each other. Whilst the majority of the material will be processed through bioremediation, soil washing is preferential for soils with greater than 5% level of contamination.
Darren Eastwood, Business Development Director at CDE commented: “The significance of this project cannot be understated. This program, the largest of its kind, aims to remediate and restore the affected areas, focusing on both environmental and socio-economic rehabilitation. The comprehensive approach of KERP includes cleaning, remediating, and revegetating the impacted zones to restore ecological balance and support the well-being of future generations.
“We have significant experience with this type of material which can be challenging to process, but we have a track record for successfully transforming this matter into valuable products which can be repurposed. And we can already see from the success of this project that washing works and is delivering the results we need. This cleanup effort is not just about restoring the land, it has major health and social implications, ensuring safer environments for communities and supporting Kuwait’s long-term sustainability goals.”
Soil washing offers a highly efficient remediation strategy, it can provide a throughput of up to 250 tph in one line which ensures fast treatment times and makes it ideal for large volumes, while the plant’s compact footprint minimises land use.
Since washing preserves the biological structure of the soil, treated soils remain biologically intact and suitable for recultivation. Soil washing also scores highly on ESG metrics thanks to its material recovery and reduced environmental liabilities.
Additionally, it’s readily integrated with downstream treatments, such as bioremediation or thermal desorption units (TDU), when needed as part of a treatment train.
Material processed through soil washing in the southern facility has an average clean output of <1%, meaning there is less than 1% contamination once washed. In the northern facility, the washed soil has an average clean output of <1%, which is then on some occasions processed by bioremediation.
Whilst work is well underway with this project, it has not been without challenge as Khaled Tubaileh, Deputy CEO, Khalid Ali al-Kharafi & Brothers explains.
“We have brought together a global consortium of contractors who are the best in the business to complete this work, but it has become more than that. We’ve developed long lasting relationships that are centred on our passion and dedication to seeing the success of this landmark project.
“These robust relationships have made it easier to navigate the challenges that we’ve been faced with. For example, when surveying the ground, we have found historical bombs which need to be managed carefully, and also the complexities that come with managing a team and fleet at the size we’re operating. As well as this, it is an intricate process and we are only able to process contaminated soil, so when extracting material, we have to be very precise, and careful not to disturb clean soil.”
One key challenge however was water management. Kuwait has no permanent rivers or lakes and receives minimal rainfall. Groundwater reserves are limited and primarily located in the north, with restricted recharge due to low precipitation.
But whilst water resource in Kuwait is limited, its water consumption per capita is among the highest in the world[1], which puts even more pressure on businesses to preserve as much water as possible. This is why water management was at the heart of the design.
During the washing process, each tonne of soil requires two tonnes of water. To secure sufficient water supplies, two 60 m³ lagoons were constructed. These lagoons store treated wastewater that is continuously recycled back into the washing operation as the plant itself is designed to recycle up to 90% of the water. This closed-loop system champions sustainability while significantly cutting operational expenses by eliminating the need for external water deliveries or fresh-water intake.
Discussing the collaborative part of this venture, Richard Hill, Chief Operations Officer at Lamor says: “It’s been an honour to be a part of this flagship project and to see the progress that has already been made. I think one of the key aspects of how this consortium has gelled is our like-mindedness. When we were appointing CDE for this project, it stood out to us that all manufacturing was completed in-house, and that’s the same approach we take at Lamor. It’s values like this that has made it easier to adapt and evolve with this initiative.”
Completion of this project will offer significant opportunity in Kuwait, with recultivation projects already underway, and the Kuwaiti government plans to grow trees and introduce animals back to the area.
It is expected these sections of the soil remediation project will be completed in early 2026.
Saudi Gulf Projects
oil & gas
11 September 20256 min readKuwait Soil Remediation Program Accelerates With Eight Million Tonnes Treated
Saudi Gulf Projects
11 September 2025
oil-gas
Energean Nets $4B In New Israeli Gas Offtake DealsEastern Mediterranean focused gas producer Energean secured $4 billion worth of new Israeli gas offtake contracts in the first half of the year, the group said on Thursday, bringing its contract pipeline to $20 billion over the next two decades.
However, the London-listed group cut its annual production forecast for the second time in nearly four months because of a temporary production suspension in Israel in June.
Energean, which aims to expand in its core locations, including Israel and Egypt and is seeking new business in West Africa, also reported a 11% drop in its core profit in six months to June 30, while after-tax profit jumped nearly 24%.
It now expects this year's production at 145,000 to 155,000 barrels of oil equivalent per day (boed), down from 160,000-175,000 boed seen in May, after Israel ordered it to stop production at its Karish offshore field during its conflict with Iran.
Energean reported first-half adjusted EBITDAX (Earnings Before Interest, Taxes, Depreciation, Amortisation, and Exploration Expense) of $505 million and after-tax profit of $110 million.
In Egypt, the group estimates there is a further 3 trillion cubic feet of gas under its existing platforms, CEO Mathios Rigas told Reuters.
Offshore Israel, Energean was weighing drilling into yet untapped formations in deep Mesozoic rocks in Block 23, which could be a "new play opener for the whole East (Mediterranean)", Rigas said.
Energean would seek a partner, though, for such a complex well, which probably have to wait until stability returned to the region, he said.
Energean also expects up to 2 billion cubic metres a year from its Katlan field off Israel, due to start production in 2027, to be carried on the planned Nitzana pipeline from Israel to Egypt after that is yet to be built, Rigas said.
(Reuters - Additional reporting by Ankita Bora in Bengaluru; Editing by Harikrishnan Nair and Tomasz Janowski)
Offshore Engineer
oil & gas
11 September 20252 min readEnergean Nets $4B In New Israeli Gas Offtake Deals
Offshore Engineer
11 September 2025
oil-gas
Energean Lands $4 Billion In Israeli Gas Deals But Cuts Output Amid Conflict(Reuters) — Eastern Mediterranean focused gas producer Energean secured $4 billion worth of new Israeli gas offtake contracts in the first half of the year, the group said on Sept. 11, bringing its contract pipeline to $20 billion over the next two decades.
However, the London-listed group cut its annual production forecast for the second time in nearly four months because of a temporary production suspension in Israel in June.
Energean, which aims to expand in its core locations, including Israel and Egypt and is seeking new business in West Africa, also reported a 11% drop in its core profit in six months to June 30, while after-tax profit jumped nearly 24%.
It now expects this year's production at 145,000 to 155,000 barrels of oil equivalent per day (boed), down from 160,000-175,000 boed seen in May, after Israel ordered it to stop production at its Karish offshore field during its conflict with Iran.
Energean reported first-half adjusted EBITDAX (Earnings Before Interest, Taxes, Depreciation, Amortization, and Exploration Expense) of $505 million and after-tax profit of $110 million.
In Egypt, the group estimates there is a further 3 trillion cubic feet of gas under its existing platforms, CEO Mathios Rigas told Reuters.
Offshore Israel, Energean was weighing drilling into yet untapped formations in deep Mesozoic rocks in Block 23, which could be a "new play opener for the whole East (Mediterranean)", Rigas said.
Energean would seek a partner, though, for such a complex well, which probably have to wait until stability returned to the region, he said.
Energean also expects up to 2 billion cubic meters a year from its Katlan field off Israel, due to start production in 2027, to be carried on the planned Nitzana pipeline from Israel to Egypt after that is yet to be built, Rigas said.
Pipeline Gas Journal
oil & gas
11 September 20252 min readEnergean Lands $4 Billion In Israeli Gas Deals But Cuts Output Amid Conflict
Pipeline Gas Journal
11 September 2025
oil-gas
Turkey: Saipem Awarded New Offshore Contract For Sakarya Gas Field Development Worth Approx. 1.5 Billion UsdSaipem has been awarded a new offshore contract by Turkish Petroleum OTC for the third phase of the Sakarya gas field development project in Turkey. The value of the contract is approx. 1.5 billion USD.
Sakarya is the largest offshore natural gas field discovered in Turkey and is located about 170 km off the coast of Filyos, Zonguldak. The third phase of development entails a new dedicated floating production unit (FPU), fed by 27 wells located in the Sakarya and Amasra fields, connected by a new trunkline to the onshore facility located in Filyos, on the Turkish Black Sea coast.
Saipem’s scope of work encompasses the engineering, procurement, construction and installation (EPCI) of 8 rigid flowlines and a 24-inch diameter Gas Export Pipeline (GEP), approximately 183 km long, connecting the offshore field, at a maximum depth of 2,200 meters, to Filyos. The overall duration of the contract is approximately 3 years, while the offshore campaign will be conducted by Saipem's Castorone pipelay vessel in 2027.
Saipem has successfully completed the first phase of the Sakarya field development project awarded in 2021 and is finalizing activities related to the second phase awarded in 2023. With the signing of this new contract, the company further consolidates its presence in Turkey and its involvement in a strategic project that contributes to the country's energy independence.
Original announcement link
Source: Saipem
Energypedia News
oil & gas
10 September 20252 min readTurkey: Saipem Awarded New Offshore Contract For Sakarya Gas Field Development Worth Approx. 1.5 Billion Usd
Energypedia News
10 September 2025
oil-gas