Axel-Pierre Bois

📍#LNGTerminals📍 ✅ bp has tucked a first gas flow milestone 🎊 under its belt at a gas development off the coasts of Mauritania and Senegal 📌, which is said to be the biggest project in the oil major’s portfolio and one of the deepest, most complex gas developments in Africa 🥇. ✅ BP has confirmed the start of gas flow from wells at the Greater Tortue Ahmeyim (GTA) Phase 1 liquefied natural gas (LNG) project 🏗 to its floating production storage and offloading (FPSO) GTA for the next stage of commissioning. ✅ The GTA Phase 1 development, which is said to have the deepest subsea infrastructure in Africa 🌏 with wells in water depths of up to 2,850 meters, will produce around 2.3 million tons of LNG annually for over 20 years 💧. 📌 Source : Offshore Energy #lng #lngindustry #lngshipping #lngbunkering #gtt #mossdesign #naturalgas #shipping

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Petroleum Reserves & Resources Overview Introduction -Reserves are oil and gas volumes that can be technically and commercially produced from underground reservoirs -1P = proved reserves (low side estimate) -2P = proved + probable reserves (most likely estimate) -3P = proved + probable + possible reserves (high side estimate) -Reserves determine the economic value of an oil company -Reserves changes impact an oil company’s share price -If oil and gas volumes are NOT commercial, they are NOT reserves -Uneconomic oil and gas volumes are referred to as resources -Resources can be contingent (sub-commercial) or prospective (undiscovered) PRMS: Petroleum Resources Management System -Framework used to define and estimate reserves and resources -Developed by the SPE, AAPG, WPC, SPEE, SEG, SPWLA & EAGE -Last updated in 2018 Available from: https://lnkd.in/egBJnVRi Proved Reserves (1P) -Reserves that are certain to be technically and commercially producible -Have a higher than 90% chance of being produced -Existing oil and gas production wells -Liquid rate under exponential decline (pessimistic forecast) -No reservoir pressure support (no water flooding, etc.) Proved reserves can be classified into the following categories Proved Developed Producing (PDP) reserves -Active production (can be recovered with existing wells) Proved Developed Not Producing (PDNP) reserves -Existing production that is shut in due to issues that have economic solutions (e.g. subsea choke failures, pipeline failures) Proved Undeveloped (PUD) reserves -Approved for development (e.g. infill wells and workovers) -Justified for development (e.g. undrained fault blocks, workover opportunities, gas inlet pressure reduction projects) -Require significant expense to bring online -PUD vs probable classification: If there is no oil-water-contact depth from well log data, then classify oil above oil-down-to depth as PUD reserves, classify oil below oil-down-to depth as probable reserves Probable Reserves (2P minus 1P) -Reserves that are not yet proved -Have a 50 – 90% chance of being technically and commercially producible -Have a fair to good probability of being recovered -Liquid rate under hyperbolic decline (pressure support) -Extensions to proved area (e.g. nearby fault blocks) -Increase in STOOIP volumes (deeper fluid contact depth, etc.) -Increase in oil recovery factors (improved water flooding) Possible Reserves (3P minus 2P): -Reserves that currently cannot be regarded as probable -Have a 10 – 50% chance of being technically and commercially producible Static / Contingent Resources -Oil and gas volumes undeveloped due to size, location, technological, economic, or political issues -Small STOOIP volume -Heavy oil reservoirs (low oil gravity) -Stranded fields -Limited gas export infrastructure -Production beyond field licence dates -Conflict zones

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Last week, the French Commission de régulation de l'énergie published a crucial prospective report on carbon capture, transport, storage, and utilization (CCUS). I see this report as a great perspective on the ways to accelerate CCUS deployment in France.   Spanning from January 2023 to July 2024, the report emphasizes the shift away from the energy crisis and the vital decisions undertaken to align the energy sector with decarbonization goals. As Emmanuelle Wargon rightly points out in Les Echos : "CCUS is a key element in achieving our decarbonization goals, particularly where no accessible technology exists." Indeed, for sectors such as steel, cement, and chemicals, where there are limited technological alternatives, CCUS stands out as a critical complementary solution.   The stakes are significant: the International Energy Agency (IEA) estimates that global CCUS needs will exceed 5,000 MtCO2 captured annually by 2050. It is therefore imperative to strengthen support for CCUS. Among the 11 recommendations of the report, the focus is on building social acceptability, ensuring flexible regulation of the value chains, setting strategic upfront planning, and fostering close collaboration between public and private stakeholders.   At Vallourec, we are fully committed to this transition. Our high-performance tubular solutions are ready to meet this challenge, by ensuring the safe transport and storage of CO2 through robust and reliable infrastructure.   I am convinced that CCUS is not only a strategic lever to achieve carbon neutrality, but also a driver of transformation for tomorrow’s industry and economy !   For more information, here is the report : :https://lnkd.in/e7Shr6DF  

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A breakthrough with Invertible Neural Networks?   In geophysics we need to determine subsurface model parameters from a set of measurements. Usually, the forward process from parameter- to measurement-space is reasonably well-defined, whereas the inverse problem is ambiguous: multiple parameter sets can result in the same measurement. To fully characterize this ambiguity, the full posterior parameter distribution, conditioned on an observed measurement, must be determined. Hence, not only the best value but also its uncertainty. Traditionally this is done using Bayesian inversion, demanding prohibitive compute time, however.   Very promising for this task are Invertible Neural Networks (INNs). Unlike classical neural networks, which attempt to solve the inverse problem directly, INNs focus on learning the forward process, using additional latent output variable distributions z to capture the information otherwise lost. Due to invertibility, a model (extended with latent model parameter distributions ε) of the corresponding inverse process is learned implicitly. Given a specific measurement and a chosen distribution of the latent variables, the inverse pass of the INN provides the full posterior parameter space. INNs are capable of also finding multi-modalities in parameter space, uncover parameter correlations, and identify unrecoverable parameters (ε).   Ref: Ardizzone et al., arXiv:1808.04730v3 Anybody with practical experience using INN?

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check out how Danomics can help you get your data ready to rock.

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This study delves into the potential of CO2 storage by leveraging CO2 fracturing technology in shale reservoirs. The study suggests that around 1000 future wells in China's Gulong shale oil reservoirs could harness similar storage potential, amounting to a storage capacity of nearly two million tons by 2030. While sounding impressive, remember that last year, all the world's nations combined pumped nearly 38.2 billion tons of carbon dioxide into the air from the burning of fossil fuels such as coal and oil, according to new international calculations on global emissions published in the journal Nature Climate Change.

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Harness the power of data and technology to boost your reservoir's performance. Our approach identifies the key factors affecting your field, using advanced analytics to pinpoint opportunities for enhanced oil recovery (EOR) and optimize production. We benchmark your performance against global standards, helping you uncover strategies that drive greater efficiency and profitability. Stay ahead of the curve by making informed decisions that lead to improved outcomes. 👉 https://lnkd.in/ecrF_Bds

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Some thoughts on ILX : (musings from the desk of retired geologist) ILX is the common acronym for ‘Infrastructure Led Exploration’. It is what you often hear about nowadays and it is commonly used in conjunction with the term ‘Advantaged Resources’ because it leverages new discoveries on existing infrastructure and facilities to bring them online cheaper and faster instead of a slower and more expensive stand alone greenfield development. It all sounds good on paper but there are a few things you should know about it. Basins are amenable to ILX if there are facilities with specifically designed spare capacity or old producing fields and facilities in good shape and with significant ullage. It also requires a govt , a willing competitor, or a system to facilitate facilities sharing with other operators. There should be significant rem YTF (and sufficient traps) in the basin to make it a worthwhile endeavor and Basin Mastery / extensive well and 3D data sets is a requirement for a sustained program. There are certain basins out there (i.e. GOM, Australia NW Shelf) that contain numerous large undeveloped discoveries and these will obviously compete with ILX and make tie backs to non operated existing facilities more competitive/ challenging. ILX rewards are typically (except in some cases) an order of magnitude smaller than normal stand alone exploration targets but the risks may not be necessarily proportionally lower because these kind of opportunities were probably classed as risky/ immaterial and passed over during the initial stages of basin exploration. Field decline rates are typically fast due to inherently smaller targets and the business can best be described as a ‘treadmill with limited breathing space’ if the primary aim is to maintain or grow a production business (assuming ILX is not targeting a new high impact play). This exploration strategy may not be suitable for everybody as it is very manpower intensive and unlikely to be transformative for most companies. Nevertheless …  this strategy may appeal to companies with large in-basin declining legacy assets and large acreage positions, smaller niche companies or startups. These are some example areas which may make ILX sense. I have excluded W Canada, US Lw 48, Russia, Ukraine, China and M East from this list. #OilGasExploration #ILX #Oil #Gas #ExplorationStrategy #MatureBasins #ProductionDecline

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🎥 New TPA / NotebookLM AI Episode Alert! 🎙️ E.13 From Blind Spots to Breakthroughs: Crude Oil Pipeline Insights with QIC Assess 🔹 Crude oil and NGL shipping pipelines might seem like simple structures, but their operations are anything but static. 🔹 Internal corrosion, driven by dynamic conditions like intermittent flow, oil-water slippage, and episodic ingress of contaminants, accounts for 80% of crude oil / liquid pipeline failures. 🔹 In this Trusted Pipeline Advisor podcast episode, we take a deep dive into how QIC Assess revolutionizes corrosion management. 🚀 What You’ll Learn in This Episode: ✅ Why traditional methods fall short in addressing real-world pipeline operations. ✅ How QIC Assess uses advanced hydraulic modeling (PIPESIM, OLGA-S) to create a high-resolution map of corrosion vulnerabilities. ✅ Insights into hidden root causes: stagnant water zones, oxygen ingress, and upstream contaminants. ✅ Targeted solutions like optimized pigging strategies and MEG injection to mitigate risk. A real-world success story showcasing significant cost savings and extended pipeline lifespan. This is more than just a discussion—it's a call to action for proactive, data-driven pipeline integrity management. 💡 QIC Assess offers a paradigm shift in managing internal corrosion for crude oil pipelines. By addressing the hidden root causes behind the majority of failures, it empowers operators to move beyond reactive maintenance to a proactive, data-driven approach. Chapters: 00:00 Introduction to QIC Assess and Corrosion Management 00:53 The Origins of NeoCorr Engineering 02:05 Formation of the Internal Corrosion Technical Subcommittee 02:53 Advanced Engineering Models and Simulations 03:33 The Evolution of QIC Assess 04:33 Introduction to QIC Assess Technology 05:07 Understanding Pipeline Corrosion Dynamics 05:38 How QIC Assess Works 08:11 Mitigation Strategies and Recommendations 13:52 Case Study: QIC Assess in Action 15:20 Conclusion and Call to Action Subscribe to the TPA podcast or visit us at the [www] trustedpipelineadvisor web-site for more insights and case studies. 🎧 Subscribe to the Trusted Pipeline Advisor Podcast Channel: Stay ahead of the curve with expert insights into corrosion mitigation and pipeline integrity. Together, let’s build a safer, smarter energy future. 🔎 YouTube: @trustedpipelineadvisor 🔎 Spotify: TPA #Innovation #PipelineIntegrity #Leadership #ContinuousImprovement #ProactiveManagement #PipelineIntegrity #CorrosionManagement #OilAndGas #PipelineSafety #QICAssess #FlowModeling #HydraulicAnalysis #AdvancedAnalytics #InnovationInEnergy #ProactiveSolutions #CorrosionControl #PipelineInnovation #EnergySolutions #notebooklm #oilandgasai #slms #sms #leadership #qualitymanagement

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➡️ 🛠 Utilizing Cold Energy from LNG to Liquefy CO2 In this video, SOFREGAZ SAS Head of Process and Safety, Nicolas Cosqueric introduces an impactful topic: liquefying CO₂ using the cold energy from LNG. This innovation showcases how LNG terminals can play a critical role in reducing emissions and enhancing energy efficiency, aligning with the energy sector's push towards sustainability and decarbonization. In this 15-minute video, discover: ✅ The technology behind CO₂ liquefaction with LNG cold energy ✅ How this innovation supports the transition to net-zero goals ✅ Sofregaz's commitment to delivering cutting-edge solutions for a cleaner future Source ➡️ https://lnkd.in/g9RnCYWb #LNG #regasification #CO2 #LCO2 #liquefaction #Sofregaz #process Jennifer SIALINO Jabir BEN HAJ TAIEB 🇵🇸🇱🇧🇲🇦

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Even 6C is not enough for the high integrity inversion we need. Onshore 6C has been around for a while and SLB showed (quite a while ago) how to deploy a production system onshore which affords enhanced noise attenuation and spatial aliasing using 6C (though tensor simplifies at a free surface). There are a couple of companies 'playing' with 6C in the marine environment with one of the biggest companies utilising a novel sensor with a polarised piezoelectric lattice which they acquired from ION when they went under. At SEG/IMAGE they may well show just how what we have been able to do onshore can translate to offshore with respect to enhanced noise attenuation and spatial aliasing. OK, this is a good development but one certainly cannot use superlatives to describe this. So where does the paradigm we need come from. The paradigm will come from a sensor which affords not just 2nd order derivative (6C) but 3rd order derivative sensitivities to invert with much higher integrity for Vp, Vs, Qp, Qs and......density. Yes density! ultimately allowing accurate inversion of the orthorhombic anisotropic stiffness tensor. These rock property inversions are the principal data clients need to derisk, especially in new energies and infrastructure emplacement. Is there one in development? Yes.

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The Untold Story of U.S. Crude Oil Production Growth Unlock Premium Strategies Here: https://energyrogue.com Join us in this enlightening video conference as we delve into the intriguing history of U.S. crude oil production. Our expert speaker walks you through pivotal moments since 1990, revealing the ups and downs of this vital industry. Don't miss out on this essential exploration! #CrudeOil #USProduction #OilHistory #EnergySector #VideoConference #OilIndustry #EconomicGrowth #SpeakerInsights #OilTrends #LearnAboutOil

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As the country continues facing political uncertainties and divisions we can expect more similar situations like this in Libya as it has shown a tremendous resilience regarding its oil production after every single massive oil and gas facilities blockades and shutdowns.

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If you're a reservoir engineer, imagine a single platform for reservoir surveillance, prediction, simulation, and optimization. What if you can: • Build simulation models (single-well, multi-well, or field-scale) in just a few clicks, and test development ideas in minutes instead of months. • Create machine learning models to predict the next best infill      wells or IOR candidates. • Use CRM models to quantify flow connectivity and optimize production. • Forecast well production with DCA, DA, CRM, and simulation— all in a fraction of the time. And what if you could do all this while monitoring reservoir performance live? To top it off, imagine data preparation, model building, storage, and execution—all automated in the cloud. 𝗜𝘁'𝘀 𝗻𝗼𝘁 𝗶𝗺𝗮𝗴𝗶𝗻𝗮𝘁𝗶𝗼𝗻 𝗮𝗻𝘆𝗺𝗼𝗿𝗲. We've spent the last 3 years in ESGWAY building this platform. Stay tuned for 𝗥𝗲𝘀𝗲𝗿𝗪𝗶𝘀𝗲™: The Future of Reservoir Management. #ReservoirManagement #ReserWise

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Last week, a significant milestone was reached as Amina Benkhadra, Director General of ONHYM - National Office of Hydrocarbons and Mines, and Charles Tautfest, President of Esso Exploration International Limited, signed two reconnaissance contracts at ONHYM headquarters. These contracts cover the Safi-Essaouira Offshore and Agadir-Ifni Offshore areas, located off the coasts of Safi, Essaouira, Agadir, and Sidi Ifni. The deal signed by Esso Exploration International Limited, a subsidiary of ExxonMobil Corporation, marks the American company's return to Morocco as the North African country continues to build momentum of #oilandgas #exploration onshore and offshore. Currently, ONHYM collaborates with 14 companies through 19 petroleum agreements and one Reconnaissance Contract, advancing Morocco's hydrocarbon potential as part of its national strategy. For even more updates on the energy industry attend AOW, 7-10 October 2024. Book your ticket here: https://lnkd.in/etHnFAEz #EnergySector #GlobalPartnerships #HydrocarbonExploration #MoroccoEnergy #ExxonMobil

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Algeria is on the brink of finalizing a deal with Chevron Corp to develop a large hydrocarbon field. Energy Minister Mohamed Arkab has indicated that Sonatrach, the state-run energy firm, is expected to sign the agreement in the coming days. Furthermore, reports suggest that Algeria is set to enhance its natural gas production by signing contracts with ExxonMobil Corp. by the end of the year. #Algeria #NaturalGas #EnergyIndustry

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