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A Game-Changer for a Nation's Economy? Pakistan is on the brink of a transformative energy breakthrough with the discovery of a major oil and natural gas reserve in its territorial waters. According to local reports, this find is one of the world’s largest, with some estimates ranking it as the fourth-largest oil and gas reserves globally. This hydrocarbon discovery has the potential to drastically alter Pakistan’s economic landscape, offering hope amid the country’s ongoing financial struggles. A Historic Oil & Gas Discovery The discovery comes after a three-year geographic survey conducted in partnership with an allied nation, confirming the presence of substantial hydrocarbon deposits. The relevant Pakistani departments have already briefed the government on the findings, with proposals for bidding and exploration under consideration. If exploration proceeds, this reserve could significantly bolster Pakistan's economic prospects by reducing the country's reliance on energy imports. The Promise of the Blue Water Economy This massive find underscores the potential of Pakistan’s "blue water economy," a term used to describe economic opportunities tied to maritime resources. Beyond oil and gas, the ocean holds a wealth of valuable minerals and elements, offering additional avenues for economic development. A senior security official has emphasized that immediate action is necessary to capitalize on this opportunity. The discovery could reverse the country’s dire economic fortunes, but the process of drilling wells and extracting the resources may take years. A Long Road to Extraction While the news is promising, industry experts are cautioning us. Former Oil and Gas Regulatory Authority (OGRA) member Muhammad Arif has noted that there are no guarantees until further analysis and drilling commence. The exploration process alone could require an investment of $5 billion and take up to four or five years to yield results. Arif also highlighted the potential impact of the discovery on Pakistan’s energy independence. The country could reduce its reliance on liquefied natural gas (LNG) imports if the reserves are primarily gas. If oil were the main resource, Pakistan could cut down significantly on imported crude. However, these benefits will only be realized if the reserve is efficiently extracted and proves as vast as initial projections suggest. World's 4th Largest Oil & Gas Reserves Found in Pakistan's Waters What’s Next for Pakistan? Despite the cautious optimism, this discovery marks a significant moment in Pakistan’s energy history. The country’s geographic location, with access to the Persian Gulf and key shipping routes, positions it well to become a major player in the global energy market. The development of this reserve could also lead to substantial foreign investment, further improving the nation’s economic outlook. With the right infrastructure, investment, and political stability, Pakistan has the chance to not only meet its domestic energy needs but also become a regional energy hub. Recent Discoveries in the Energy Sector In addition to this offshore discovery, MOL Pakistan made three gas finds in the TAL Block located in Khyber Pakhtunkhwa last month. These smaller discoveries and the new offshore find offer the country a rare opportunity to enhance its energy security and economic stability. Conclusion While much remains uncertain, the discovery of a major oil and gas reserve in Pakistan’s waters holds immense promise. The economic implications are vast, with the potential to turn Pakistan into a key energy player on the world stage. However, the extraction path is long and costly, requiring patience, investment, and a clear strategy. For now, Pakistan stands at the threshold of a new era in energy development—one that could reshape the nation's future for generations to come. Pakistan Oil and Gas Consultants Aries One’s clients—ranging from small operators, private equity firms, oilfield service and technology companies to major oil companies (NOCs and IOCs) —need to stay informed and agile. Our services, including Pakistan Oil and Gas Consultants, Consulting , Project Management , Staffing , Technology, and Training , are designed to help you navigate these changes and optimize your operations. For more information on how Aries One can support your business, visit   www.aries-one.com .

The latest Baker Hughes Rig Count has provided valuable insights into the current state of drilling activity across the United States, Canada, and international regions. Here's a detailed breakdown of this week's rig count movements: United States:  The U.S. rig count saw a slight decline, with the total number of rigs dropping by 2, bringing the count to 583. This marks a significant decrease of 48 rigs compared to last year. The continued decline in the U.S. rig count suggests a cautious approach by operators, possibly due to fluctuating oil prices and ongoing economic uncertainties. Canada:  In contrast, Canada experienced a modest increase, adding 1 rig this week, bringing the total to 220. The year-over-year data reveals a more optimistic picture, with an impressive gain of 33 rigs. This uptick highlights the resilience of Canada's energy sector, as companies continue to explore and develop new opportunities despite challenges in the global market. International:  The international rig count remained unchanged this month, steady at 934. However, this represents a decrease of 23 rigs compared to the previous month and 27 rigs fewer than last year. The global rig count fluctuations underscore the varying levels of activity across different regions, driven by factors such as geopolitical events, regulatory changes, and market demand. Rig Count Update Understanding the Rig Count Trends The changes observed in the rig count are crucial indicators of the energy sector's health and provide valuable insights for companies, investors, and stakeholders. The decline in U.S. rigs may reflect a cautious stance amid economic uncertainty, while Canada's growth signals a strong commitment to energy development. Internationally, the stability in the rig count suggests that global energy players are navigating complex market dynamics, balancing new investments with existing operations. How Aries One Can Support Your Operations Navigating the complexities of the energy sector requires expertise, foresight, and adaptability. At Aries One, we offer a comprehensive range of services designed to support every aspect of your energy project, from day rate Drilling Supervisors Consulting , Project Management , Staffing , and technology solutions. Our deep understanding of the industry's challenges and opportunities enables us to provide tailored solutions that drive success. Whether you're looking to optimize your drilling operations, enhance project management efficiency, or ensure compliance with regulatory standards, Aries One is your trusted partner. We are committed to helping you achieve your goals while safeguarding your operations and reputation. Explore our services and discover how we can support your success in a dynamic and ever-changing industry.

Venezuelan state-owned PDVSA and the Nigerian capital company Veneoranto Petroleum Ltd. signed an agreement to develop two natural gas prospects in the areas of Barracuda, located in territorial waters of the Gulf of Venezuela bordering Colombia, and Boca de Serpiente, located in Delta Amacuro state, bordering a territory under claim by Guyana. "I am pleased that the investment process for gas production from the Deltana platform has been accelerated. Very soon we will be exporting gas to Africa," said Venezuelan President Nicolás Maduro, who was present at the signing of the agreement Aug. 8 in Caracas. The agreement was signed by the Minister of Petroleum and President of PDVSA, Pedro Rafael Tellechea, and the representative of Veneoranto Petroleum Limited, Arthur Eze. Venezuela & Nigeria Partner on Major Offshore Gas Prospects Veneoranto is the subsidiary created in Venezuela by Atlas Oranto, a Nigerian company in the oil and natural gas area. Th offshore prospect called Barracuda in the Gulf of Venezuela, is estimated to have reserves of 20 Tcf of natural gas and about 2 trillion barrels of condensate, according to available official information. According to studies PDVSA carried out between 2013 and 2014, this prospect could be larger than the Cardón IV field, where the Italian ENI and the Spanish Repsol made an important gas and condensate discovery in 2009. PDVSA is seeking investors for 25 development opportunities in offshore Gulf of Venezuela waters, which have the advantage of nearby onshore infrastructure, the Paraguaná Peninsula, where the two major refineries Amuay and Cardón are located, according to previous reports. Colombia and Venezuela share an extensive 2,219-km land border. They also share a maritime border over which there are territorial disputes. Details of the Boca de Serpiente prospect, located in the area known as Plataforma Deltana, are not available. The prospect is located about 200 km from the neighboring island of Trinidad and Tobago, and borders the Atlantic Ocean and the area under claim with Guyana. In addition to this new agreement with Veneoranto, Venezuela signed with Trinidad and Tobago five agreements related to gas exploration and production to develop offshore gas reserves, according to previous report July 24. Official figures show that Venezuela has massive proven reserves of 303 billion barrels of oil and 200 Tcf of natural gas. "With these investments we will be the fourth natural gas reserve, it is important that investments keep flowing. We are reliable safe partners," Maduro said. Maduro was reelected in presidential elections July 28, but these results have been contested, triggering protests. The opposition candidate Edmundo Gonzalez declared himself president-elect, based on results of tally sheets that give him a victory with 67% of the votes. The National Electoral Council has not published the electoral results, as established by the electoral law, alleging a cybernetic attack on the system. The Carter Center, an international observer that the Maduro-controlled CNE invited, confirmed that Edmundo Gonzalez won the elections in Venezuela and that there is no evidence of hacking, according to media reports from Aug. 8. "With investors, we have no problem. To investors from Europe and the United States I say, hurry up, here are the opportunities, but if they let yourselves be disturbed by the political noise, well, welcome countries of BRICS," Maduro added. Maduro, as he faces political pressure from Western countries, said Aug. 2 that Venezuela may transfer rights to develop oil and gas projects to BRICS countries. "If these people from the north and their partners in the world make the mistake of their lives, then those oil blocks and those gas blocks that were already signed will go to our allies in the BRICS," Maduro said. BRICS includes Brazil, Russia, India, China and South Africa. From the beginning of 2024, Egypt, Ethiopia, Iran, and the United Arab Emirates joined. Saudi Arabia was also invited to join, but has yet to officially confirm membership. If Saudi Arabia became a member, the group would control 42% of global oil production and 35% of total oil consumption, US Energy Information Administration data indicates. Maduro has said previously that Venezuela is considering joining BRICS. Russia holds the BRICS presidency for 2024 and has invited Maduro to the BRICS leaders summit due to take place in the Russian city of Kazan Oct. 22-24. Venezuela - Consultores Petroleo y Gas Aries One’s clients—ranging from small operators to major oil companies—need to stay informed and agile. Our services, including Consultores Petroleo y Gas, Consulting , Project Management , Staffing , Technology, and Training, are designed to help you navigate these changes and optimize your operations. For more information on how Aries One can support your business, visit   www.aries-one.com . Source: S & P Global

HOUSTON/DENVER, Jan 9 (Reuters) - The White House is summoning oil executives to discuss potential investment in Venezuela on Friday, and while a preliminary list of attendees features the big names of American oil - Chevron (CVX.N), opens new tab, Exxon Mobil (XOM.N), opens new tab and ConocoPhillips (COP.N), opens new tab - it also includes several smaller independents and private equity-backed players. Only the largest U.S. oil producers have the scale and capacity to operate in Venezuela and have experience doing so, said an oil industry source. The inclusion of smaller domestic companies in the meeting is notable given that they mostly operate in the U.S. Continental Resources, which bills itself as the biggest privately owned oil and natural gas producer in the world, will be in attendance, as will HKN Inc., which was formerly known as Harken Energy. Several of the companies have connections to Denver, Colorado, the home turf of Secretary of Energy Chris Wright and a relatively small hub for oil and gas activity compared to other parts of the United States. Oil output in PADD 4, the production region that includes Colorado, totaled 1.02 million barrels per day in October, according to the latest data from the U.S. Energy Information Administration. PADD 3, which includes states like Texas and New Mexico, produced 10.28 million bpd that month. Raisa Energy, which acquires non-operated stakes in energy assets and has a Venezuelan CEO, is based in Denver and backed by investment funds Citadel and Ares Management. Tallgrass Energy - a midstream company with pipeline and terminal assets in areas including the U.S. Rocky Mountains and Oklahoma - and Aspect Holdings, which lists former Speaker of the U.S. House of Representatives Kevin McCarthy as an independent director, are also headquartered in Denver. The Department of Energy did not immediately respond to a request for comment. Raisa, Tallgrass, and Aspect did not immediately reply to questions about any previous discussions they may have had about Venezuela ahead of the Friday meeting. Many of the smaller firms and independents may not have as much experience with heavy oil that is typical in Venezuela, but they will be familiar with lighter oil around Lake Maracaibo and shale that has not yet been tapped, said a long-time oil industry executive. "They don’t have as much capital as an Exxon, Chevron or ConocoPhillips, but independents are known to move much faster. Their cost structure is lower, so they can drill wells much cheaper than the majors," the person said. Explore our services: https://www.aries-one.com Source: https://www.reuters.com/business/energy/white-house-oil-meeting-venezuela-includes-independents-strong-links-denver-2026-01-09/

Australia’s offshore oil and gas industry is facing a significant challenge: how to decommission its aging infrastructure. However, recent developments in forecasting have brought a positive shift in the outlook for the sector. A new report from global energy consultancy Xodus estimates the long-term cost of removing offshore oil and gas infrastructure will be A$43.6 billion (A$66.8 billion in inflation-adjusted terms) through 2070 significantly lower than the previous estimate of A$61.8 billion from 2020. This updated cost projection comes as Australia’s energy sector gains more clarity and expertise in offshore decommissioning, signaling both financial relief and improved planning for operators, policymakers, and investors. In this blog, we’ll explore the reasons behind the revised cost estimate, the potential for future savings, and what this means for the industry’s future. Australia offshore decommissioning costs ; What’s Behind the Revised Estimate? The revised estimate reflects better forecasting techniques, improved data, and a more refined understanding of the full scope of decommissioning activities. Over the past few years, Australia's offshore oil and gas industry has gained significant experience in well decommissioning, pipeline removal, and vessel mobilization. With more accurate cost modeling tools and a clearer understanding of the technical challenges, the energy sector is now better positioned to plan for decommissioning activities in a more cost-effective manner. The revised estimate covers: Over 700 wells to be decommissioned 7,600 km of pipelines to be removed 520 subsea structures to be dismantled These numbers paint a comprehensive picture of the massive undertaking ahead. Yet, thanks to improved industry knowledge, costs are projected to be much lower than previously anticipated. What Does This Mean for Operators and Policymakers? For operators and policymakers, this update is a crucial piece of the puzzle. The revised forecast of A$43.6 billion offers a more accurate financial roadmap for long-term planning and budgeting. This provides better certainty, which is key to ensuring safe and sustainable decommissioning practices, especially as Australia’s offshore energy assets begin to age and come to the end of their operational life. Andrew Taylor, Head of Advisory APAC at Xodus, emphasized the importance of this updated analysis: “Accurate cost forecasting is critical as Australia develops a safer and more sustainable decommissioning sector.” This revised forecast helps operators and government bodies better prepare for the financial implications of decommissioning and avoid any surprises down the line. Opportunities for Further Savings Even though the updated figure of A$43.6 billion represents a significant reduction, there’s still room for further savings in the sector. According to the Xodus report, there are several opportunities to reduce costs even more, including: Coordinated Decommissioning Campaigns By combining decommissioning activities and coordinating efforts between different operators, the cost of removing assets can be significantly reduced. Collaborative campaigns can optimize resource use, cut down on mobilization costs, and reduce the number of vessels required, leading to overall savings. Technology Improvements New technologies are continually improving the efficiency of decommissioning processes. For instance, advancements in automation, robotics, and data analytics can help streamline well plugging, pipeline removal, and subsea structure dismantling. As these technologies evolve, they will likely reduce the time and labor required, leading to further cost reductions. Leveraging Offshore Wind Development Another potential avenue for cost reduction lies in leveraging the growth of offshore wind construction. The development of offshore wind farms could provide economies of scale in vessel mobilization, port utilization, and infrastructure, making decommissioning activities more efficient. Challenges Ahead Despite the positive outlook, there are still challenges to overcome. The report highlights the need for substantial investment in critical infrastructure to support decommissioning activities. Ports, vessels, and recycling facilities will need to be upgraded to handle the volume of work expected in the coming decades. Moreover, while the forecast for decommissioning costs is lower, the sector will still need to manage a range of technical and regulatory challenges. Ensuring that decommissioning is conducted safely, sustainably, and in line with environmental regulations will remain a priority. The Future of Offshore Decommissioning in Australia This new outlook on offshore decommissioning costs in Australia is a step in the right direction. By reducing the projected cost from A$61.8 billion to A$43.6 billion, the industry has gained a clearer, more realistic understanding of what lies ahead. The shift towards smarter planning, better forecasting, and more advanced technology is helping to create a safer, more sustainable, and cost-effective decommissioning sector. As Australia moves toward a future of energy transition and growing offshore wind development, the lessons learned from offshore oil and gas decommissioning will be invaluable. Operators and policymakers alike will need to continue collaborating, adopting new technologies, and investing in the infrastructure required to support these efforts. For those in the industry, this is an opportunity to take a proactive approach in planning and executing decommissioning projects ensuring a future that is both economically viable and environmentally responsible. The revised estimate of A$43.6 billion for offshore decommissioning in Australia is a significant development for the energy sector. It reflects improved forecasting, better data, and a more efficient approach to well, pipeline, and subsea removal. As technology continues to evolve and the industry works together to streamline decommissioning processes, further cost reductions may be possible. This update is a positive sign that Australia’s offshore decommissioning efforts are on track for a more sustainable and financially predictable future. Explore our services: https://www.aries-one.com/ Source: https://www.worldoil.com/news/2025/11/19/new-analysis-lowers-australia-s-projected-offshore-decommissioning-costs-to-43-6-billion/

The Bureau of Ocean Energy Management (BOEM)  has finalized plans for a December 10 lease sale in the U.S. Gulf of Mexico , offering 80 million acres  across more than 15,000 unleased blocks . The sale covers about half of the Gulf’s Outer Continental Shelf (OCS) , spanning waters from 9 to 11,115 feet deep  and 3 to 231 miles offshore . This lease round is the first of 30 mandated under the One Big Beautiful Bill Act (OBBBA) , which requires two Gulf lease sales annually through 2040. The initiative marks a significant policy shift toward expanding access to offshore energy resources and boosting domestic production capacity. Expanding Alaska’s Offshore Outlook in this New Offshore Lease Sales In addition to the Gulf sale, BOEM has proposed a 1 million-acre lease offering in Alaska’s Cook Inlet , scheduled for March 2026 . This will be the first of six planned sales  in the region through 2032, as outlined in the OBBBA. The last Cook Inlet lease sale was held in 2022, attracting only one bid — but this new round, supported by improved market conditions and regulatory clarity, could reawaken industry interest in Alaska’s offshore potential. Both upcoming lease sales will be set at a 12.5% royalty rate , following adjustments under the OBBBA to encourage participation and investment in U.S. offshore resources. Renewed Confidence in U.S. Offshore Energy The planned lease sales reflect a broader resurgence of confidence  in U.S. offshore development. With over 80 million acres available , operators have the opportunity to pursue new frontier blocks, integrate existing infrastructure, and advance lower-carbon deepwater strategies through technology-driven efficiency . The combination of regulatory clarity, infrastructure maturity, and global energy demand  positions the U.S. Gulf as a continued anchor for offshore production — while Alaska’s Cook Inlet offers strategic diversification in a high-potential basin. Balancing Energy Expansion and Sustainability These new lease rounds come at a time when the global offshore sector is balancing the dual goals of production growth and emissions reduction . Advances in subsea technology, digital monitoring, and FPSO efficiency  are helping operators deliver projects that are both economically and environmentally sustainable. As offshore activity accelerates, the U.S. remains a key player in ensuring stable energy supply while transitioning toward a lower-carbon future. At Aries One , we support operators and investors involved in offshore projects across every stage of development. Our expertise helps clients execute with precision, safety, and efficiency. 🔗 Explore our Services:   www.ariesoneenergy.com 📖 Source:  Upstream Online – BOEM unveils plans for next lease sale in US Gulf

Weekly Rig Count Overview According to Baker Hughes , global rig activity remains resilient despite ongoing market uncertainty, reflecting disciplined growth and targeted capital deployment across regions. United States:  548 rigs ( +1 week | -37 year ) Canada:  198 rigs ( +5 week | -19 year ) International:  1,084 rigs ( +8 month | -72 year ) These figures suggest a gradual rebound in North American drilling , supported by stable commodity prices and a renewed push toward year-end project completions. U.S. Rig Count: Marginal Growth Amid Efficiency Gains The U.S. rig count inched higher this week, signaling steady confidence among shale producers. Even with a 37-rig decline year over year , operators continue to deliver strong output through: Improved drilling efficiency  and longer laterals Selective capital allocation  toward high-return basins Technology integration  to optimize well productivity This combination allows producers to sustain output while maintaining cost discipline and shareholder returns — a hallmark of the current upstream investment cycle. Canada Rig Count: Strong Seasonal Momentum Canada posted the most significant weekly increase, adding five rigs  as winter drilling preparations accelerate. Activity remains concentrated in Western Canada’s Montney, Duvernay, and Clearwater plays , driven by: Growing natural gas demand  for LNG exports Attractive condensate pricing Increasing service-sector readiness for Q4 campaigns Canadian operators appear poised for a robust winter drilling season , reflecting confidence in long-term gas development. International Rig Count: Stable Growth in Offshore and Emerging Markets The international rig count  remains unchanged month to month at 1,084 active rigs, though it reflects steady offshore expansion  in regions such as West Africa, the Middle East, and Latin America .Long-cycle developments and national oil company (NOC) investments  continue to anchor growth, offsetting declines in mature basins. As global demand stabilizes and deepwater projects ramp up, international activity is expected to gradually strengthen into 2026 . Explore our Services:   www.aries-one.com Source:   Baker Hughes Rig Count

According to Baker Hughes , global rig activity remains resilient despite ongoing market uncertainty, reflecting disciplined growth and targeted capital deployment across regions. United States:  548 rigs ( +1 week | -37 year ) Canada:  198 rigs ( +5 week | -19 year ) International:  1,084 rigs ( +8 month | -72 year ) These figures suggest a gradual rebound in North American drilling , supported by stable commodity prices and a renewed push toward year-end project completions. U.S. Rig Count : Marginal Growth Amid Efficiency Gains The U.S. rig count inched higher this week, signaling steady confidence among shale producers. Even with a 37-rig decline year over year , operators continue to deliver strong output through: Improved drilling efficiency  and longer laterals Selective capital allocation  toward high-return basins Technology integration  to optimize well productivity This combination allows producers to sustain output while maintaining cost discipline and shareholder returns — a hallmark of the current upstream investment cycle. Canada Rig Count : Strong Seasonal Momentum Canada posted the most significant weekly increase, adding five rigs  as winter drilling preparations accelerate. Activity remains concentrated in Western Canada’s Montney, Duvernay, and Clearwater plays , driven by: Growing natural gas demand  for LNG exports Attractive condensate pricing Increasing service-sector readiness for Q4 campaigns Canadian operators appear poised for a robust winter drilling season , reflecting confidence in long-term gas development. International Rig Count : Stable Growth in Offshore and Emerging Markets The international rig count  remains unchanged month to month at 1,084 active rigs, though it reflects steady offshore expansion  in regions such as West Africa, the Middle East, and Latin America .Long-cycle developments and national oil company (NOC) investments  continue to anchor growth, offsetting declines in mature basins. As global demand stabilizes and deepwater projects ramp up, international activity is expected to gradually strengthen into 2026 . Aries One Perspective: Navigating Market Momentum The current rig trends reflect a balanced global outlook  — mature basins emphasizing efficiency and cost control, while emerging regions drive growth through new exploration and infrastructure investment. At Aries One , we help clients interpret and respond to these shifts with integrated solutions that enhance operational readiness and project success: Consulting:  Market intelligence, rig forecasting, and asset planning Project Management:  End-to-end oversight for drilling and completion progra ms Staffing:  Access to skilled engineering and field professionals worldwide Technology:  Digital workflows for performance and emissions optimization Training:  Workforce development to ensure safe and sustainable operations 🔗 Explore our Ser vices:   www.aries-one.com 📊 Source:   Baker Hughes Rig Count

Equinor and its partners have officially begun production at the Bacalhau field , located in the pre-salt Santos Basin  off the coast of Brazil. Situated in ultra-deep water exceeding 2,000 meters , Bacalhau represents one of the largest oil and gas developments in the country — with recoverable reserves of more than 1 billion barrels of oil equivalent (boe) . The field is developed using one of the most advanced floating production, storage, and offloading (FPSO)  vessels in operation today — a 370-meter-long, 64-meter-wide unit with the capacity to produce 220,000 barrels of oil per day (bpd) . Advanced Engineering Meets Lower Carbon Operations Bacalhau’s combined-cycle gas turbine (CCGT)  system represents a major step forward in sustainable offshore production. By integrating power generation with waste heat recovery, the FPSO achieves an expected CO₂ intensity of around 9 kg per boe  — significantly below global deepwater averages. The field also employs advanced emission abatement  measures across flaring, processing, and storage systems, setting a new industry benchmark for low-carbon, cost-efficient production  at scale. Phase 1 Development and Project Scope of Bacalhau Production Phase 1  includes 19 subsea wells  — a mix of producers and injectors — which will be brought online progressively to achieve steady-state production. MODEC , the FPSO contractor, will operate the vessel during the initial production phase, after which Equinor  will assume operatorship for the remainder of the license period. The project partners include: Equinor (40%, operator) ExxonMobil Brasil (40%) Petrogal Brasil (20%)   (a Galp | Sinopec JV) Pré-Sal Petróleo S.A (PPSA)   (government-managed PSA partner) Driving Efficiency, Scale, and Value Creation According to Anders Opedal , Equinor’s President and CEO, “Bacalhau represents a new generation of projects that bring together scale, cost-efficiency, and lower carbon intensity. With this development, we are strengthening the longevity of our oil and gas production and securing value creation for decades to come.” This development underscores Brazil’s leadership in deepwater innovation , supported by robust regulatory frameworks and growing investment in pre-salt exploration and production. Supporting the Future of Deepwater Projects At Aries One , we partner with global operators, EPC contractors, and investors to deliver the next generation of offshore and deepwater developments  — safely, efficiently, and sustainably. Our expertise spans: Consulting:  Field development planning, risk assessment, and cost optimization. Project Management:  Execution oversight for FPSO, subsea, and drilling programs. Staffing:  Deployment of skilled professionals across engineering and operations. Technology:  Digital tools that enhance performance and emissions tracking. Training:  Capacity building for local workforces and operational readiness. Explore our Services:   www.ariesoneenergy.com Source:   Upstream Online – Equinor Starts Production at Bacalhau Field Offshore Brazil

According to the latest Baker Hughes Rig Count , the global oil and gas drilling landscape remains dynamic, reflecting shifting capital flows and regional investment priorities. United States:  547 rigs ( -2 week / -39 year ) Canada:  193 rigs ( +3 week / -26 year ) International:  1,084 rigs ( +8 month / -72 year ) While overall global activity is steady, the mix between regions tells a nuanced story about where operators are focusing their efforts amid evolving market conditions. U.S. Rig Count: Consolidation Amid Efficiency Gains The slight decline in U.S. rigs signals ongoing capital discipline  among shale operators. Companies continue to prioritize free cash flow and operational efficiency  over aggressive drilling programs.Despite fewer active rigs, productivity per well remains strong , driven by technology adoption, longer laterals, and precision completions. This trend supports stable output levels even as rig counts fluctuate. Canada Rig Count : Modest Uptick as Seasonal Drilling Returns Canada’s modest week-on-week increase reflects seasonal recovery  and renewed activity in key basins such as the Montney and Duvernay .Producers are preparing for winter drilling programs , supported by firm natural gas prices and continued demand for LNG export supply  commitments. International Rig Count : Momentum Builds in the Middle East and Africa The international rig count continues to rise, with notable growth in the Middle East, Latin America, and West Africa . These regions benefit from long-term investment cycles and national oil company (NOC)  development strategies focused on resource expansion and energy security. Rising offshore activity — from deepwater West Africa to the Eastern Mediterranean  — highlights ongoing confidence in frontier exploration and development despite global price volatility. Strategic Insight: A Balanced Global Outlook The current rig trends underline a balanced upstream environment  — mature basins focusing on efficiency, and emerging regions expanding through new discoveries and large-scale projects.This equilibrium supports both short-term production stability and long-term supply diversification as the energy transition  reshapes capital priorities. 🔗 Explore our Services:   www.aries-one.com 📊 Source:   Baker Hughes Rig Count

Italian energy major Eni  has strengthened its position in Côte d’Ivoire’s offshore sector  with the acquisition of the I-707 exploration block , located near its 2024 Calao discovery . The move expands Eni’s footprint to 10 offshore blocks  across the country, reinforcing its long-term commitment to West Africa’s emerging deepwater play. Eni Côte d’Ivoire deepwater exploration - Strategic Growth and Synergy Potential The I-707 block  spans 2,926 square kilometers  in water depths ranging from 1,000 to 3,000 meters . Its proximity to the Calao field offers a strategic opportunity for infrastructure-led exploration —a model designed to accelerate development timelines and optimize capital efficiency. Eni now holds a robust production base in the region, exceeding 62,000 barrels of oil per day  and 75 million cubic feet of gas per day . The company’s portfolio approach in Côte d’Ivoire underscores its focus on synergy, scalability, and gas-led growth —key elements of its broader African energy strategy . West Africa’s Deepwater Momentum Eni Côte d’Ivoire deepwater exploration also highlights the growing momentum within the Ivorian sedimentary basin , a zone attracting increasing attention from global operators and investors. With established infrastructure, rising local capability, and favorable geology, Côte d’Ivoire is positioning itself as a regional deepwater hub . Supporting Energy Expansion in Emerging Frontiers At Aries One , we help energy companies navigate the technical, operational, and workforce challenges of deepwater exploration and project delivery . From consulting  and project management  to staffing , technology , and training , our integrated services ensure safe, efficient, and strategic execution across every project phase. 🔗 Explore our Services:   www.ariesoneenergy.com Source: https://www.upstreamonline.com/exploration/eni-acquires-ivory-coast-exploration-block/2-1-1879249

Petrobras is moving one step closer to beginning exploration in Brazil’s Foz do Amazonas basin , located in the Equatorial Margin—a region rich in potential but under intense environmental scrutiny. Petrobras Moves Closer to Amazon Oil Drilling The company recently conducted a large-scale emergency drill  to test its readiness for spill response, a requirement ahead of final licensing approval. This milestone reflects Petrobras’ commitment to demonstrating operational safety as it seeks to balance exploration with ecological protection. A $3 Billion Investment Petrobras has allocated $3 billion  for the drilling of 15 exploration wells  in the basin over the next five years. This initiative could unlock significant reserves and bolster Brazil’s position in global oil markets, particularly as offshore developments gain momentum. Balancing Energy and Environment While the Equatorial Margin presents an opportunity to expand Brazil’s offshore production, it also raises debates about environmental risks in sensitive Amazonian waters. Industry observers will be watching closely to see how Petrobras navigates regulatory, environmental, and social challenges while pursuing growth. Supporting Complex Energy Projects At Aries One , we specialize in guiding energy clients through high-stakes, technically challenging projects—from offshore exploration to project management and workforce solutions. Our experience ensures that operators have the right strategies, people, and resources in place to execute safely and efficiently. 🔗 Explore our Services:   www.aries-one.com