In celebration of a new, one-of-its-kind carbon dioxide (CO2) research well that will be drilled at the LSU Petroleum Engineering Research and Technology Transfer (PERTT) Laboratory, ExxonMobil last week hosted a panel comprised of academic, policy and regulatory experts who provided valuable insight on how carbon capture, utilization and storage investments are creating educational and economic opportunities for Louisiana residents. The CO2 research well — a collaboration between Louisiana State University, ExxonMobil, Halliburton, the U.S. Economic Development Administration and Louisiana Economic Development — will enable students, researchers, regulators, and industry to study CO2 in all three of its phases under realistic field conditions. The new well will not be operational and will not inject any CO2 into the subsurface. The well will be solely used for research purposes, and LSU expects it to have significant research value. Research will include testing and developing safety and monitoring technologies, understanding CO2 flow behavior in various downhole conditions, and validating the predictions of computer models or bench-scale experiments at the field scale. Watch the video below to see a recap of the celebration:
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🚨 **Key Takeaway from #SPE (Society of Petroleum Engineers) European Energy Conference in Turin: The Essential Role of Microseismic Networks** 🚨 As we wrap up this insightful three-day SPE conference in Turin, one message stands out: the critical importance of microseismic networks for monitoring Underground Gas Storage (UGS), CO2 injection, and particularly for managing reservoirs in overpressure conditions. 🔍 **Highlights from Two Key Papers:** 1. **Lessons Learned From the Southwest Regional Partnership on Carbon Sequestration (Paper SPE - 220068)**: B. McPherson (University of Utah) and R. Balch (Petroleum Recovery Research Center, New Mexico Tech) shared findings from the Aneth field. CO2 injection into an aquifer identified microseismic events aligned along a fault within the monitoring domain, directly linked to injection activities. This demonstrates how microseismic networks provide vital data to understand and manage subsurface dynamics during storage and sequestration operations. 2. **The Practice and Effect of Underground Gas Storage Expanding the Range of Operation Pressure Beyond the Original Reservoir Pressure (Paper SPE - 220019)**: H. Jiang and colleagues from PetroChina and Baker Hughes discussed increasing the injection pressure at the XiaGuoShi field. Despite 60 microseismic events recorded during the pressure boosting period occurring outside the internal domain, the use of microseismic networks effectively monitored reservoir integrity, resulting in an increase of approximately 300 Mscm of working gas per cycle. 🛠️ **Why This Matters:** These studies reaffirm the importance of advanced microseismic networks for ensuring the safety and effectiveness of operations, especially in high-pressure contexts. They not only provide crucial real-time monitoring data but also help prevent potential risks, enhancing reservoir management and optimization. Let's continue to leverage these technologies to drive innovation and safety in our industry! 🌍🔬 Seismix #SPEConference #Microseismic #UGS #CO2Injection #ReservoirManagement #PetroleumEngineering #Innovation #SafetyFirst
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We’re celebrating 40 years of testing and research 🎉 with a throw-back of the first testing project funded by the ERC participants back in 1993! 💥 The founding four member companies were Exxon Research and Engineering, Phillips Petroleum, Texaco, and Union Carbide. The topic selected that year was “Upgrade of Windows to Mitigate the Glass Fragmentation Hazard from Vapor Cloud Explosions”. Fun fact: This was our very first shock tube!! The project scope was small, but this shock tube produced a nice blast wave shape despite its simple design. The 2024 project year includes twelve cutting edge research projects. Learn more about this joint-industry program - see our comment below. #explosion #researchanddevelopment #oilandgas #chemical #riskmanagement #BetterRiskManagementStartsHere #40YearsofBakerRisk
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Led by the excellent Eric Tenthorey with SLB, our paper on the geomechanics of hydrogen storage in a depleted gas field is out. Using realistic injection rates and volumes, the study shows the risk of fault reactivation and geomechanical damage to the cap rock is similar to natural gas storage. So no show stoppers. There is a big but though. In the medium term, it is unlikely we will be filling depleted gas fields with 100,000s of tonnes of hydrogen. This means there will be mixing with the gas already present in the reservoir (i.e. methane) and any cushion gas. In our case study, hydrogen recovery per cycle was only 70-80% (10 cycles over 10 years). It means there could be significant separation and cleanup required as part of the storage costs. A real need to make sure well design and injection/production strategies are optimised to minimise losses. Hsiao Wun Moh, Ratih Puspitasari, Marie Ann Giddins, Zachariah John, Rashmin Dandekar, Olivia Suriyanto
Senior Technical Advisor at Geoscience Australia, Geomechanics, Carbon Capture and Storage, Low Carbon Geoscience
I'm super happy to see our latest work on the geomechanics of hydrogen storage come out in print in the International Journal of Hydrogen Energy. Pdf can be downloaded at https://lnkd.in/e4xyz9RQ This work was done as part of the Australian Government's Exploring for the Future Program, led by Geoscience Australia. Thanks to all that were involved.
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Will you be attending next week's PESA QLD 2024 Symposium? If so, be sure to connect with the Gas & Energy Transition Research Centre researchers who will be delivering presentations! The Centre's presentation line-up at this year's Symposium include: • State of Origin - not just a footy game anymore - Prof David Close • Improving Low-Permeability Clastic and Coal Seam Gas Reservoir Characterisation using the Diagnostic Fracture Injection Test - Prof Ray Johnson Jr. • Is that a leak or a leek? Identifying if methane and CO2 are (not) leaking from reservoirs to aquifer water resources or surface - Dr Julie Pearce The PESA QLD Symposium, which you can register for at https://lnkd.in/gUxuBmDD, brings members of Queensland's petroleum exploration and production industry together to discuss industry affairs from a technical, economic and social perspective. #uq #research #oil #gas #energy #geoscience #geology PESA Energy Geoscience
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Hello Everyone and thank you for joining us weekly during our live Wed(NSI)days! We are excited for this week’s session of Wed(NSI)days! Our team had a great time at the SPE 2024 Hydraulic Fracturing Technology Conference (HFTC) back in February, and hopefully you had a chance to attend as well! We are always keeping an eye on publications in the industry and HFTC is one of the best events with the highest quality of technical content. This week our team is doing a round-up and review of some of the presentations during HFTC and our take on some of them. Join us to hear our thoughts on some of the best presentations and great discussion about the direction our industry is trending. Join us this week to participate in what is sure to be a great discussion! Wednesday, March 6th at 9 am CST Topic: HFTC 2024 Paper Highlights Speakers: Mike Smith, Ph.D., C.E.O, NSI Technologies, LLC JiaYao "J.Y." Deng, Ph.D., VP Technical Services, NSI Technologies, LLC Dario Stemberger, VP Engineering, NSI Technologies, LLC Host: Dante Guerra, Ph.D., President, NSI Technologies, LLC FREE Registration Link: https://lnkd.in/e8QWq5A #innovation #technology #energy #oilgas #production #oilandgas #cloud #hydrocarbons #offshore #oilandgasindustry #oilfield #oil #gas #petroleum #drilling #oilindustry #energystrong #onshore #oilandgasexploration #permianbasin #upstream #permian #completions #frac #shale #eagleford #reservoir #geomechanics #hydraulicfracturing #bakken
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As carbon capture, utilization, and storage (CCUS) becomes a critical part of the decarbonization strategy, lessons learned from enhanced oil recovery (EOR) can help provide a path forward. For more than four decades, Halliburton has used CO2 in places like the Permian Basin in Texas to help customers maximize reservoir output. In the past, engineers have used this technique to pipe naturally occurring CO2 underground to oil fields. In his main stage session at the Carbon Capture & Hydrogen Technology Expo, Steven Knabe, global director of Evaluation and Production explained the relationship between EOR and CCUS. Click the link below to read his key takeaways.
Enhanced oil recovery (EOR) is the unsung hero of CCUS
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As carbon capture, utilization, and storage (CCUS) becomes a critical part of the decarbonization strategy, lessons learned from enhanced oil recovery (EOR) can help provide a path forward. For more than four decades, Halliburton has used CO2 in places like the Permian Basin in Texas to help customers maximize reservoir output. In the past, engineers have used this technique to pipe naturally occurring CO2 underground to oil fields. In his main stage session at the Carbon Capture & Hydrogen Technology Expo, Steven Knabe, global director of Evaluation and Production explained the relationship between EOR and CCUS. Click the link below to read his key takeaways.
Enhanced oil recovery (EOR) is the unsung hero of CCUS
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As carbon capture, utilization, and storage (CCUS) becomes a critical part of the decarbonization strategy, lessons learned from enhanced oil recovery (EOR) can help provide a path forward. For more than four decades, Halliburton has used CO2 in places like the Permian Basin in Texas to help customers maximize reservoir output. In the past, engineers have used this technique to pipe naturally occurring CO2 underground to oil fields. In his main stage session at the Carbon Capture & Hydrogen Technology Expo, Steven Knabe, global director of Evaluation and Production explained the relationship between EOR and CCUS. Click the link below to read his key takeaways.
Enhanced oil recovery (EOR) is the unsung hero of CCUS
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I’m thrilled to share our latest publication in the Journal of Petroleum Exploration and Production Technology. Together with Professor Ehsan Khamehchi, we’ve developed a groundbreaking packer fluid designed for high-temperature and high-pressure oil and gas wells. 🔬 Title: “Development of a novel packer fluid for high-temperature and high-pressure oil and gas wells with using design of experiments and artificial intelligence”
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On November 1st, my paper was presented at the 12th Brazilian Congress on R&D in Oil and Gas (PDPetro), one of the leading events in the industry in Brazil. Although I couldn't be in Brazil for the event, I am very grateful to my coauthor, Ana Júlia da Silva, for her support in representing our work, and to Professor Anibal Alexandre Campos for his guidance throughout the research. Our research is titled "Proportional-Integral Control of a Nonlinear Two-Phase Separator in the Presence of Slugging." This research focuses on optimizing the control parameters, specifically the proportional gain and integration time of the controller. The goal is to enhance the performance of a two-phase separator, which is crucial in oil and gas processing. This study is part of the project "Optimized Use of Dispersants in Submarine Spills," resulting from a collaboration between Universidade do Estado de Santa Catarina and Petrobras, regulated by ANP Resolution 03/2015, which addresses investments in R&D by the National Agency of Petroleum.
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