Saudi Arabia and Qatar Face Energy Infrastructure Disruptions

Saudi Arabia has reported disruptions to critical energy infrastructure, including its East-West Pipeline, which serves as an important alternative route for moving crude without relying entirely on the Strait of Hormuz. The pipeline has a reported capacity of around 4-5 million barrels per day, equivalent to roughly 4-5% of global oil supply. Recent attacks temporarily disrupted operations, highlighting the vulnerability of alternative export routes during the conflict.

The disruptions have placed additional focus on the resilience of Middle East energy infrastructure and the importance of maintaining routes that can support oil transportation beyond the Strait of Hormuz. Qatar has also faced damage at the Ras Laffan industrial complex, affecting LNG production infrastructure. The disruption comes as Qatar works with international LNG producers to secure additional supply arrangements. This situation underscores the importance of restoring regional gas infrastructure and maintaining reliable export capacity.

UAE Assets and Gulf Energy Supply Routes

The UAE has likewise experienced disruptions affecting major energy assets, including the Ruwais refinery, Habshan gas facilities, Shah gas field and Fujairah port. Restoration of these facilities could support the gradual normalization of regional refining, gas processing, petrochemical feedstock and energy logistics.

Beyond repairing damaged facilities, the proposed funding could accelerate investments in alternative pipelines, export terminals and other infrastructure designed to diversify energy transportation routes. Such investments could form part of wider efforts to strengthen Middle East energy infrastructure while reducing dependence on established transportation routes. If implemented, the initiative could therefore influence both the pace of infrastructure recovery and the longer-term structure of Gulf energy supply chains. However, the proposal remains under discussion, meaning its final size, participants and deployment timeline could change.

Namibia’s Minister of Industries, Mines and Energy Modestus Amutse announced on Monday that the TotalEnergies bidding group had been selected as the successful bidder following an open competitive bidding process. Its trading company, TOTSA, has been designated as the supplying member under the agreement. The three-month arrangement includes approximately 246.9 million litres of diesel and 98.4 million litres of petrol. The first shipment is expected to arrive in November, marking the start of the bulk fuel supply deal.

Discounted Fuel Pricing to Deliver Savings

The successful bid provides discounts against the Basic Fuel Price (BFP), offering 61 cents per litre on diesel and 71 cents per litre on petrol. These discounts result in a weighted average discount of 63.85 cents per litre. According to the Ministry, the pricing arrangement is expected to deliver savings of about N$220.5 million during the three-month supply period. The savings will accrue to the national fuel price account, known as the slate, which is managed under the National Energy Fund.

The Ministry said the latest bulk fuel supply deal represents another reduction in Namibia’s fuel import costs. Previous supply arrangements had shifted from suppliers charging premiums above the BFP to fuel being supplied at the benchmark price. In the latest tender, all four participating companies offered to supply fuel at discounts to the BFP, while none requested a premium.

“For years, Namibia paid more than the Basic Fuel Price, the official reference price for imported fuel, to have its fuel supplied: suppliers charged a premium on top of that benchmark,” Amutse said.

“In the last supply round, the Ministry removed that premium entirely: fuel was supplied at the BFP itself, with nothing added. This round, we have gone a step further,” he added.

Government Continues Competitive Fuel Procurement

Amutse said the N$220.5 million saving would strengthen the government’s ability to keep domestic pump prices stable. The Ministry said the bids were evaluated using several criteria, including bidder qualification, pricing, security-of-supply risks and the standing and track record of each supplier. Amutse said the government would continue using competitive bidding to procure Namibia’s bulk fuel requirements while ensuring security of supply.

Focus on Asian Buyers and New Supply Sources

Portfolio Expansion Across Multiple Regions

Evaluate Forging Capabilities

The first to take into consideration is the real capability of the manufacturer to make forging. If you choose a Forged valve manufacturer that is reliable, he should possess more than just the basic metal forming equipment. It should be aware of the influence of the various forging processes on the flow of the grain, mechanical properties, dimensional accuracy and performance of the components. KSN Forging provides services of custom hot forging, forged steel production, closed die forging, open die forging, ring rolling, heat treatment, machining and valve forging. It can forge parts like valve bodies, bonnets, stems, discs, plugs, seat rings and other pressure containing parts. The selection of forging processes can be made depending on geometry and production requirements to meet the desired performance.

Check Experience With Oil and Gas Applications

Oil and gas pipeline valves must have reliable materials and manufacturing processes. Customers need to look at the manufacturer’s previous oil & gas forging experience, including pipelines, pressure equipment, refinery, LNG and other energy equipment. KSN Forging is a source of custom components for upstream drilling and production, offshore platforms, midstream pipeline transmission, downstream refining, LNG and gas processing plants, pumps, compressors and valve systems. It has oil and gas forging capacity, such as forged valve bodies, bonnets, stems, flanges, pipeline connectors, wellhead components, couplings and other special components.

Confirm Custom Manufacturing From Drawings

All industrial projects may have various dimensions, pressure specifications, materials and connection specifications. Therefore, it is important to select a manufacturer that is able to manufacture components for technical drawings. KSN Forging provides OEM and custom manufacturing services for 2D drawing, 3D model or physical sample. This enables the customers to order parts that conform to their engineering needs thereby not limiting their options to standard parts. The company may also provide forged blanks or semi-machined parts or fully-machined components based on the project.

Review Material Selection

Another essential factor to take into account when choosing a Forged valve manufacturer will be the materials they’re using. Carbon steel, alloy steel, stainless steel, duplex stainless steel, super duplex materials or nickel based materials are applied in pipeline applications based on the pressure, temperature, corrosion and service conditions. KSN Forging has a wide range of steels and specialty alloys on which to work. Its oil and gas manufacturing information also contains materials like ASTM A105, A350 LF2, A694 grades, stainless steel, duplex stainless steel, super duplex stainless steel and nickel alloys. This range enables manufacturers to choose the material based on the applications’ needs.

Discuss Quality Inspection Procedures

The quality control system of the oil and gas forging supplier should be systematic, starting from raw materials, forging, heat treatment, machining, and finally the inspection. The quality checks should be in accordance with the project requirement and industry standards. KSN Forging offers a variety of inspection services such as chemical analysis, mechanical testing, dimensional inspection, ultrasonic testing, magnetic particle testing, liquid penetrant testing, positive material identification and third party inspection services. The processes ensure that the parts produced will subsequently have the required specification before they are delivered.

Request Traceability Documentation

For pipeline and energy projects, documentation is crucial as customers could require to know the origin of materials, manufacturing history, test results and final dimensions. A professional Forged valve manufacturer will be able to give documentation to aid full product traceability. KSN Forging would be able to furnish material certificates, dimensional inspection reports, mechanical examination reports, heat treatment records, non destructive testing reports, hardness reports, chemical analysis reports, and many other quality documents based on the project requirements. These records enable customers to have good quality control and product verification all the way down the line.

Consider using Complete Manufacturing Support

An added benefit is that you are able to work with a manufacturer that can deal with a number of stages of production. The customer can save the trouble of arranging different suppliers to forge, heat treat, machine and inspect the products, while enjoying the advantages of a comprehensive manufacturing process. The services KSN Forging offers include forging, heat treatment, CNC machining, precision finishing and inspection. For oil and gas forged parts, parts can be made in various production conditions based on customer needs, including forged blanks, finished machine products, etc.

Have students compare Technical Support and Communication

The technical aspects of a supplier are frequently overlooked. Before making a product, a manufacturer should be able to take a look at the drawings and understand the material specifications so they can recommend a suitable forging and understand any considerations before manufacturing. KSN Forging assesses technical information of customers to obtain proper production routes such as open die forging, closed die forging or ring rolling. This engineering solution can be used to help make sure that the chosen process is in line with the geometry, volume and performance of the component being produced.

Choose a Manufacturer for Long Term Reliability

When choosing a pipeline valve supplier, price isn’t the only factor to take into account. Purchasers should look for forging experience, material knowledge, customization, inspection systems, documentation, and experience with challenging industries. KSN Forging provides a custom hot forging service, forged steel production, closed die forging, valve forging, heat treatment, machine and quality inspection for industrial customers. Companies that buy pressure resistant parts for pipelines and energy can minimize quality risks by selecting a manufacturer that has experience with pipeline and energy parts and has robust documentation and manufacturing flexibility.

Conclusion

Selecting the appropriate Forged valve manufacturer is key to pipeline applications for safe, reliable and long lasting performance. Buyers should take the forming ability, material, customization, quality inspection, traceability, technical support into account before choosing. KSN Forging provides custom forged steel parts, forged steel production, closed die forging and valve forging according to customer drawings and projects. It has experience in providing solutions for oil, gas and energy applications, and its oil and gas forging solutions benefit from complete traceability documentation and quality inspection reports. The collaboration with a reliable and experienced supplier enables companies to acquire valve parts in a forged state that comply with rigorous technical and quality standards, ensuring stable industrial processes.

Under the terms of the agreement, Chevron will provide technical advice and support to the Iraqi side during negotiations concerning development of the giant field, according to the Oil Ministry. The technical consultancy arrangement forms part of a wider process that has brought Chevron closer to assuming a development role at West Qurna 2. In the interim, Iraq’s Basra Oil Company has been managing the field while Baghdad and Chevron continue discussions over the terms of a new arrangement.

Information Exchange Supports Further Discussions

The latest step follows a series of engagements between Chevron and Iraqi authorities. In July 2026, the Basra Oil Company and Chevron signed a non-disclosure agreement covering the exchange of technical and financial information required to assess the field and support further negotiations. That agreement was designed to establish a foundation for a potential future partnership. Chevron has since continued commercial discussions with Iraq. In August 2026, the company said its work on West Qurna 2 was based on agreements signed earlier in the year and that it was sharing its expertise with the Iraqi government as talks over the field progressed.

West Qurna 2 Remains Strategic to Iraq’s Oil Output

Located in Basra province in southern Iraq, West Qurna 2 is among Iraq’s largest oil fields and has estimated recoverable reserves of about 14 billion barrels. Prior to disruptions caused by regional security conditions and export restrictions, the field was producing roughly 450,000 to 480,000 barrels per day, making it an important contributor to Iraq’s overall crude output. Production from the field began in 2014.

Chevron’s expanding involvement also reflects a broader change in Iraq’s oil-sector partnerships. The company has been pursuing several projects with Baghdad, including development opportunities involving the Nasiriyah and Balad fields as well as exploration blocks. In February 2026, Iraq and Chevron signed agreements concerning the development of other hydrocarbon resources.

Export Infrastructure Adds Importance to Development Talks

The future of West Qurna 2 has gained additional importance for Baghdad as Iraq seeks to expand production while facing constraints affecting traditional export routes. The prolonged disruption around the Strait of Hormuz has underscored Iraq’s reliance on maritime routes for transporting crude to international markets and encouraged the government to consider alternative export infrastructure.

Establishing a long-term development arrangement for West Qurna 2 remains important for Baghdad as it seeks to sustain output from one of its largest oil fields, attract international investment and reinforce the country’s energy infrastructure. The latest technical consultancy agreement therefore establishes Chevron’s formal technical participation in the continuing negotiations, while Iraq works to determine the commercial, operational and development terms of a potential long-term partnership.

For U.S. businesses running service vans, delivery vehicles, or mixed fleets, the objective is a repeatable routine. Dispatch needs vehicles ready for work, fleet managers need usable fuel data, and accounting needs charges that can be allocated and paid.

Choose a fuel card that fits the work

Business Fleet Solutions describes Shell Card Business and Shell Card Business Flex alongside purchase limits, Driver IDs, fueling reports, and online card administration. Its homepage names ClearView Snap and ClearView Essentials for reporting and Shell Account Manager for account management. It advertises more than 12,000 Shell stations for Shell Card Business and over 95% of U.S. fueling stations for Business Flex. It also advertises rebates of up to six cents per gallon. These are provider descriptions and an advertised ceiling; confirm the selected product’s current terms, fees, eligible purchases, and available features before enrollment.¹

Evaluate the program against actual routes. Identify regular fueling stops, required fuel types, operating hours, and emergency locations. Check those stops against the card’s acceptance network, keeping acceptance and rebate eligibility separate.

Request a sample transaction export and an accounting demonstration. Ask about purchase restrictions, driver prompts, reporting delays, and card suspension. Include reporting subscriptions, transaction charges, integration costs, and payment terms in the evaluation.

Assign responsibilities before issuing cards

Build a card register with the vehicle identification number or internal asset ID, a masked card identifier, assigned driver where applicable, department, supervisor, activation date, and status. Use identifiers that match your fleet management software and accounting records.

A vehicle-based card should remain associated with that asset. A driver-based arrangement must identify the vehicle used for each purchase. For shared vehicles, document driver changes and confirm that the provider supports the assignment model.

Recommended ownership can be kept simple:

In a small fleet, one person may cover several roles. Identify who approves changes and verifies charges. Include card return, suspension, reassignment, and access removal in employee departure and vehicle disposal procedures.

Configure purchase controls and train drivers

Translate the fuel policy into available account restrictions. Define permitted products, spending or volume limits, and purchase timing or frequency. Test a normal purchase and a permitted exception before expanding the rollout.

Base limits on tank capacity, expected travel, and approved auxiliary equipment. Local service vans and emergency vehicles may need different settings. Review limits when routes, fuel prices, or assignments change.

Give drivers a short fueling procedure:

Confirm that the station accepts the card and supplies the vehicle’s approved fuel.

Use the correct card and personal Driver ID or PIN where supported.

Enter accurate vehicle and odometer information when prompted.

Retain the documentation required by company policy.

Report a declined purchase, lost card, incorrect entry, or unexpected charge through the designated contact.

Have drivers practice the decline procedure. Specify who authorizes alternate payments, what evidence accounting needs, and when problems must be reported. Discourage shared credentials and unexplained workarounds.

Connect fuel transactions to fleet and accounting records

The U.S. Department of Energy’s FleetDASH methodology uses fuel transaction data including fuel type, purchase date, station location, quantity, and organization codes. It identifies potential problems with miscoded fuel, delayed or missing transactions, inaccurate locations, and incorrect vehicle information. These findings describe a federal fleet data system, not a commercial card specification.²

Before automating imports, trace a sample of real transactions from the provider’s record to the vehicle history and accounting entry. Use the documented issues to guide your checks.

Map fields and prevent duplicate imports

Map transaction identifiers, purchase dates and times, card references, vehicle and driver IDs where available, fuel type, gallons, amount, merchant, and cost center. Identify which fields the provider supplies. Standardize fuel grades, units, and handling of local time.

Confirm compatibility before choosing a supported connector, an application programming interface, or a CSV file import. CSV files transfer structured rows of data between systems. Verify transfer frequency, cost, and responsibility for failures.

Use a stable transaction key where available. Test duplicate imports, credits arriving after charges, and records for retired vehicles. Assign someone to resolve failed or unmatched records, and preserve original exports so corrections remain traceable.

Add telematics where it answers a specific question

Use GPS tracking or telematics when location, mileage, or vehicle operation needs investigation. A station purchase does not establish a continuous route. Request a demonstration connecting the exact card program and telematics platform.

Align timestamps and vehicle assignments before comparing locations. Allow for delayed posting, incorrect identifiers, or location errors. Investigate discrepancies before drawing conclusions about fuel theft.

Review exceptions on a regular schedule

Match the review schedule to operational risk and confirmed reporting delays. Assign a supervisor to check new transactions regularly, with a backup for absences.

Check for purchases outside approved hours, closely repeated fills, amounts inconsistent with vehicle capacity, missing odometer entries, and inactive assignments. Confirm which checks are automated and which need manual review.

Review the original transaction, assignment, driver’s explanation, and relevant dispatch or vehicle records. Distinguish coding errors, policy exceptions, training issues, and confirmed misuse. Record evidence, corrective action, and the completion date.

Track unresolved items by age and count. Adjust rules that repeatedly flag legitimate work, and require approval for looser controls. Count prevented losses as savings only with evidence of an avoided expense.

Reconcile fuel expenses and measure performance

GSA SmartPay’s federal fleet guidance describes account activity reports, exception reports, detailed transaction files, and invoice and dispute reports. Report suites vary by bank, with updates occurring after transactions or at billing-cycle close. Commercial fleets should confirm their provider’s timing and available reports.³

At monthly close, match charges and credits to the statement, allocate expenses by vehicle and cost center, verify rebates and fees, and log unresolved disputes. Define the cutoff for late transactions, payment approval, and supporting-record retention.

Use a short scorecard with definitions that remain consistent across reporting periods:

Fuel spend and gallons purchased, separated by fuel type.

Net fuel cost per gallon, with included rebates and fees identified.

Fuel cost per mile, using matched expense and mileage periods.

Unmatched transaction rate and unresolved exception age.

Administrative time spent processing and reconciling transactions.

Calculate miles per gallon using matched distance and fuel intervals. Partial fills and changing tank levels can distort short-period estimates. For vehicles operating stationary equipment, consider an additional measure reflecting that work.

Compare vehicles with similar assignments. Fuel spend can change with prices, mileage, loads, routes, or maintenance. Investigate unusual trends and record operational changes so their results can be reviewed.

Test the workflow before expanding the program

Pilot the workflow through a complete billing cycle with representative drivers, vehicles, and routes. Record the existing process, then test purchases, credits, declines, late records, and reassignment. Extend the pilot if important cases remain untested.

Agree on acceptance criteria. Require matched assignments or documented resolutions, a reproducible statement balance, drivers who understand the exception procedure, and an owner for each unresolved issue.

Calculate the benefit after incremental costs

Consider a hypothetical annual example: 20 vehicles buy 48,000 gallons, with 75% eligible for a four-cent rebate. Assume $720 in recurring costs and $240 for first-year setup. These are illustrative assumptions, not a provider quote or measured results.

At these assumptions, 24,000 eligible gallons cover the $960 first-year cost. That is half of the fleet’s annual volume. If the realized rebate were two cents instead, the same 36,000 eligible gallons would earn $720, leaving a $240 first-year shortfall.

This calculation assumes unchanged station prices, routes, consumption, and no rewards lost from the previous payment method. Replace those assumptions with actual results. Include additional reporting, integration, financing, transaction, or detour expenses when they apply. Compare the final purchase cost at suitable stations as well as the rebate.

Measure administrative time separately. If handling 240 monthly transactions falls from five minutes each to three, the team recovers eight hours a month. That is useful capacity. Count it as cash savings only when an actual expense, such as paid overtime or outside processing, decreases. Keep this distinction visible in the pilot review.

Expand once purchases, data transfers, exception handling, and accounting close work together. Keep an owner for each step and review the workflow when vehicles, routes, staff, or systems change.

Footnotes

1. Business Fleet Solutions: Shell Fleet Cards with Rewards and Rebates.URL: https://www.businessfleetsolutions.com/

2. U.S. Department of Energy: FleetDASH Data Processing Methodologies.URL: https://afdc.energy.gov/FleetDASH/

3. GSA SmartPay: Lesson 5 Reporting Tools.URL: https://training.smartpay.gsa.gov/training_fleet_pc/lesson05/

Under the approved arrangement, Jordan will import liquefied natural gas before regasifying it through existing infrastructure at Aqaba. The gas will then be transported through Syria to Lebanon, where it will be used for power generation, according to a Prime Ministry statement. The arrangement also adds to Jordan’s position as a regional energy hub, building on its existing role in supplying Syria with natural gas since the beginning of the year through the same mechanism.

Energy-Efficiency Measures Also Approved

Alongside the decision concerning the natural gas supply, the Cabinet approved steps to implement an energy-efficiency project across government buildings. The project will be based on energy audits and is expected to lower government energy bills by around 20 per cent. Work is scheduled to start at a number of ministries next year, with the programme subsequently set to expand to other government institutions.

Jordan, Syria and Lebanon had signed an agreement in May to cooperate on natural gas supplies after a trilateral meeting in Amman involving the energy ministers of the three countries. Minister of Energy and Mineral Resources Saleh Kharabsheh said at the time that technical preparations had been completed, contracts signed and studies conducted to rehabilitate gas transmission networks. The agreement calls for Jordan to use its infrastructure to import liquefied natural gas, regasify it and pump it to Syria through the Arab Gas Pipeline.

Regional Energy Cooperation Gains Momentum

Syrian Energy Minister Mohammad Bashir said the gas supplied through Jordan had contributed to stabilising Syria’s electricity grid. He also voiced hope that regional electricity interconnection between Jordan, Syria and Lebanon could be restored, noting that four power lines connecting Syria and Lebanon were ready on both sides. Bashir said Syria expects its natural gas production to reach 15 million cubic metres per day by the end of 2026, compared with around 7 million cubic metres currently.

Lebanese Energy and Water Minister Joseph Saddi said cooperation between the three countries was essential to rebuilding Lebanon’s energy sector on more sustainable and efficient foundations. He described the electricity interconnection project as highly important and said Lebanon was working to complete it as quickly as possible. The latest natural gas supply arrangement follows a January 2026 agreement signed by Jordan and Syria in Damascus for the sale and purchase of natural gas to supply Syria through Jordanian territory, supporting electricity generation and helping ease energy shortages. Syria has since begun receiving gas under that agreement, with supplies reaching around 4 million cubic metres per day.

The agreement is part of a contract valued at around $800 million annually, intended to secure stable energy supplies and improve services. Jordan has previously said it is ready to supply energy to Syria and Lebanon once the necessary technical arrangements are completed, particularly the rehabilitation of Syrian networks damaged during the war. Regional electricity interconnection efforts began as far back as 2001 but were suspended in 2012. Attempts to restore the links resumed in 2022 through agreements intended to supply electricity and gas to Lebanon via Syria, although financing challenges delayed implementation.

Chevron’s Venezuela oil expansion represents one of the largest energy investments currently underway in the region. This ambitious undertaking is comes just after Chevron unveiled more than $7 billion in planned investment through 2031 across three separate joint venture operations. Currently, Chevron extracts roughly 290,000 barrels per day from its Venezuelan operations, with all production exported to United States refineries. The expansion is projected to add approximately 310,000 barrels per day of additional crude capacity within the five-year timeframe.

Favorable Contract Terms and Risk Mitigation

The newly signed contract framework includes provisions that grant Chevron access to international arbitration mechanisms. This clause carries particular importance given Venezuela’s historical pattern of contract disputes and petroleum sector nationalizations.

The company has maintained operational continuity in Venezuela since 1923, a longevity that distinguishes it from other international energy firms. When Venezuela nationalized significant portions of its oil sector in 2007, ExxonMobil and ConocoPhillips were pushed out entirely. Chevron, conversely, preserved its presence through joint venture arrangements with Petroleos de Venezuela (PDVSA).

Expanded Acreage and Operational Advantages

Beyond the planned increase in drilling rigs, Chevron has secured additional acreage within the Orinoco Belt, one of the world’s largest proven oil reserves. The additional territory includes areas within the Carabobo region previously assigned to Petroindependencia, in which Chevron holds a 49 percent stake. The company also maintains supplementary development rights adjacent to its existing Petropiar operation, strengthening its competitive positioning across multiple production zones.

The Chevron Venezuela oil expansion benefits from operational efficiencies inherent to the company’s existing infrastructure. New drilling capacity can be deployed within areas adjacent to established facilities, eliminating delays associated with developing entirely new operational footprints. This geographic proximity to existing processing and export infrastructure enables faster ramp-up of production capabilities compared to greenfield development scenarios.

Broader Push for U.S. Investment in Venezuela

The expanded operations unfold alongside a substantially larger U.S.-Venezuela petroleum agreement announced recently. Venezuela granted North American Blue Energy Partners 100-year concessions covering 17 separate oil fields holding approximately 65 billion barrels of proven crude reserves. The accord incorporates governance provisions and production access guarantees for the United States government, receiving approval from Venezuela’s National Assembly on 1st September 2026.

Under the revised arrangement, ExxonMobil will assume operatorship of Papua LNG project from TotalEnergies. The companies will work together to manage the transition while maintaining ongoing project activities and meeting their commitments to the Papua New Guinea authorities and other stakeholders.

Cost Efficiency and Project Scope

The EPC tendering process has been concluded, with contract award recommendations now awaiting approval from the co-venturers. TotalEnergies said that project design optimization and the rebidding of EPC packages undertaken since 2024 have resulted in nearly $4 billion in cost savings.

Revised Ownership and Stakeholder Agreements

Following the planned back-in by Kumul Petroleum, TotalEnergies will divest a 9.1% interest in the project to existing partners. Under the revised ownership structure, ExxonMobil will hold a 34.1% stake and assume operatorship. TotalEnergies will retain a 20% interest, while Santos will hold 21%, ENEOS Xplora 2.4%, and Kumul Petroleum Holdings Limited along with MRDC will maintain a combined 22.5% stake.

The partners have also updated the 2019 gas agreement with the government of Papua New Guinea to align with the current project budget and design optimizations. Furthermore, a LNG marketing joint venture has been established between TotalEnergies and state-related entities to manage the sale of 2.4 million tonnes per annum (Mtpa) of the planned 5.6 Mtpa total output. Additionally, TotalEnergies has secured an agreement to purchase 1.5 Mtpa from the marketing joint venture for its global LNG portfolio.

Infrastructure and Production Targets

“These agreements mark decisive step towards the Final Investment Decision of Papua LNG. The transfer of operatorship enhances the project’s value creation and competitiveness by leveraging the synergies with PNG LNG during construction and operations phases. Papua LNG will enable the Company to secure significant LNG volumes, strategically located to support energy supply diversification across fast-growing Asian markets,” said Patrick Pouyanné, Chairman and CEO of TotalEnergies

Papua LNG project is planned to produce 5.6 Mtpa of LNG using gas resources from the Elk and Antelope fields in Gulf Province. The project will comprise gas processing facilities, a pipeline connecting the fields with the liquefaction facility, and LNG infrastructure located near Port Moresby.

The Junin-5 oil field CPPH replaces the existing operating model of the Petrojunin joint venture and completes a preliminary argeement executed earlier in 2026. The new contractual framework was introduced through the post-Maduro Organic Hydrocarbons Law.

Under the previous operating structure, Eni owns 40 percent in Junin-5 while PdVSA holds 60 percent. Eni said the new agreement provides for a 25-year term, with the possibility of extension, while assigning the company exclusive operational responsibility for the area.

“The CPPH, which has a duration of 25 years with the possibility of extension, grants Eni the role of exclusive operator of the Junin-5 area, with full responsibility for the technical, financial and commercial management of the project”, Eni said in an official online statement.

Eni Maintains Broader Venezuelan Operations

Eni chief executive Claudio Descalzi said, “This agreement represents a new pillar for the revival of the country’s oil and gas sector, at a historic time when energy security, based on abundant resources and diversified supply routes, is vital to global stability”.

The Junin-5 oil field agreement adds to Eni’s existing activities in Venezuela. Earlier this year, Eni’s 50:50 Venezuelan joint venture with Spain’s Repsol SA signed an agreement to relaunch production at the largest offshore gas field discovered in Latin America, as announced by Eni April 28. The Perla field in the Gulf of Venezuela is operated through the joint venture Cardón IV.

Perla, which represents about 35 percent of Venezuela’s gas demand, accounted for the bulk of Eni’s production of 64,000 barrels of oil equivalent a day in the country last year, according to Eni.

Eni and PdVSA also remain partners in PetroSucre, which operates the Corocoro offshore field, Eni confirmed when announcing the new CPPH. In addition to upstream assets, Eni retains a stake in Venezuelan methanol producer Supermetanol. The company also said it currently holds six mining licenses in the Gulf of Venezuela and the Gulf of Paria, as well as onshore Orinoco.