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ABSTRACT Reverse water gas shift reaction (RWGS) assisted by an electric field was investigated using Ce‐ and Zr‐ based catalysts in a flow bed reactor. The effect of NiO and metallic Ni deposition was investigated together with the effect of Zr loading into the ceria structure. An in‐depth chemical, structural, and electrical characterization study was conducted on the catalysts before and after the reaction, in order to establish a correlation between the physico‐chemical properties of the catalysts and the catalytic activity. Among all catalysts, Ce 0,5 Zr 0,5 O 2 prepared by sol‐gel method showed a 20% CO 2 conversion and a low energy consumption of 0.49 kWh(mol) −1 , with 91% CO selectivity. The investigation revealed a plasma discharge generation during the RWGS reaction for the supports alone, which was not observed when loading catalysts.

Abstract Perforating in high-pressure, high-temperature (HPHT) wells require extensive engineering preparation to address hazards associated with extreme downhole conditions. Mature HPHT reservoirs often exhibit significant intra-reservoir differential pressure, in some cases exceeding 400 bar between adjacent production units. These conditions, combined with bottomhole temperatures approaching 200 °C, present high risks of gun lift, differential sticking, and tool failure, particularly in multi-zone completions where perforation order is critical. Historically, coiled tubing has been the default conveyance under live-well conditions, but in multi-zone HPHT settings it typically forces a single-run interval that can expose depleted zones to damage due to high overbalance while adding cost, complexity, and surface footprint. This paper describes the engineering and execution of a wireline perforation programme in a deep HPHT completion with ~490-bar differential pressure across a >200-m gross interval. Conveyance was via a 0.28-in OD polymer-locked wireline cable with MP35N armour—a high-strength, sour-service design. The polymer fills between the armour wires better seals armour interstices to help block gas migration, and the small OD reduces drag and wellbore pressure forces on the cable enabling safe conveyance of 70–80 ft of 2 7/8-in guns per run. The perforation order followed a specific pressure-profile-driven zone-by-zone sequence: pre-job simulations (gun lift, differential sticking, and shock loads) established the initial perforating plan and real-time downhole gauge pressure after each run was used to update and re-order the next sequence. Mechanical shock-loading risk was mitigated by qualifying the shock-absorber sub beyond its nominal rating. High temperature failure risk was controlled by using a flask that protected electronics at ~200 °C as well as limiting internal tool temperature build-up by rotating flask tool use. Dynamic underbalance technique was used on select intervals to improve tunnel cleanup and near-wellbore connectivity. Across two wells, a total of 21 wireline runs (perforation plus post-perforation treatments) were successfully completed with no misruns or equipment failures and a total of ~450 m was perforated. Post-treatment pressure trends indicated improved reservoir communication. The method eliminated the need for coiled tubing, reduced operational footprint and complexity, and preserved productivity in depleted zones.

_ The dynamic realm of offshore drilling and completion continually sees the development of innovative technologies aimed at enhancing safety, efficiency, and cost-effectiveness. This edition highlights three papers showcasing transformative potential within the industry. The first paper explores the use of along-string measurements and high-speed telemetry to mitigate geohazards and improve risk management in drilling operations. This innovative approach has significantly improved operational efficiency and well placement in offshore environments. By leveraging real-time data and advanced telemetry systems, operators can make informed decisions that enhance safety and optimize drilling operations. Several case studies showcase the successful implementation and potential of this technology to revolutionize the industry. The second paper introduces a pioneering digital shaker surveillance system using computer-vision technology on a deepwater rig. In an experimental trial, a computer-vision system monitored and measured drilled cuttings in real time. The system used an optical sensor and image-analysis software to quantify and qualify cuttings during drilling operations. Data collected revealed a strong correlation between cuttings load and drilling-parameter perturbations, improving assessments of hole cleaning and wellbore stability. The system aims to boost drilling efficiency, optimize penetration rates, and prevent packoff events by autonomously characterizing drilled cuttings. The third paper discusses the evolution of riserless mechanical subsea intervention in the deepwater Gulf of Mexico through a 22-well, multiyear campaign. Advancements in deepwater subsea well-intervention technology have enabled operators to perform more-sophisticated mechanical interventions (with wireline and slickline) without the need for a riser, significantly reducing costs and operational complexity. Case studies demonstrate the benefits, challenges, and prospects of riserless well intervention. Summarized Papers in This October 2025 Issue SPE 219627 - Telemetry Approach Enables Optimal Well Placement Despite Geohazards by Stephen Pink, NOV, et al. OTC 35585 - Digital Shaker Surveillance Uses Computer Vision on a Deepwater Rig by Calvin Holt, DrillDocs, et al. SPE 224044 - Riserless Wireline Subsea Intervention in Deepwater Offers Expanded Potential by Strethen E. Townsend, BP, et al. Recommended Additional Reading at OnePetro: www.onepetro.org. SPE 220855 - Horizontal Openhole Gravel-Pack Challenges and Lessons Learned From More Than 60 Offshore Wells Performed in Peregrino Field by F.C. Colbert, Baker Hughes, et al. OTC 35995 - Integrated Workflow for Designing a Multizonal Water Injector With Intelligent Well-Completion Functionality by Vijay Rachit, ExxonMobil, et al. SPE 223800 - The Automation Advantage: Efficiency Improvements in Offshore Drilling by B. Millward, Halliburton, et al.

Acid gas chemical absorption with aqueous amine solvents is an important industrial technology for gas processing and CO2 capture. Vapor-Liquid Equilibrium (VLE) reflects the efficiency of solvents and is essential to model the thermodynamics of the absorption and solvent regeneration process. In this study, several machine learning (ML) approaches were used to develop VLE models for acid gas absorption in aqueous methyldiethanolamine (MDEA) and piperazine (Pz), namely CO2-MDEA-H2O, H2S-MDEA-H2O, CO2-H2S-MDEA-H2O and CO2-Pz-H2O systems. New experimental data are presented for the CO2-MDEA-H2O and H2S-MDEA-H2O ternary systems, and they are used to compare the accuracy of the ML models to an earlier reported activity coefficient (e-NRTL)-based thermodynamic model. For the quaternary system CO2-H2S-MDEA-H2O, the ML models and the physical model are compared using experimental data from literature, because the physical model of the quaternary system is only trained on the ternary experimental systems. The results indicate that the optimal ML approach is not systematically more accurate than the physics-based model.

Abstract Aramis is a major CCS project, currently launching the EPCI phase to be built in the North Sea offshore Netherlands. As one of the most ambitious CCS projects, with an injection capacity of 22 Mtpa, Aramis will play a crucial role in helping the EU achieve its decarbonization goals for industries with high fossil-fuel consumption. The centerpiece of the project is a nearly 200km long transport pipeline entirely buried, connecting emitters to various offshore storage sites. Nearby emitters will supply CO2-rich streams in gas phase directly from their capture facilities into a low-pressure onshore collection network. The gaseous stream will be pressurized in a compressor station and fed into the Aramis pipeline in warm conditions. More remote emitters will supply CO2-rich streams in liquid phase transported by ships (the expected temperature is down to -25 °C) or by a long-distance pipeline (ambient temperature). The mixture of streams from diverse types of emitters and / or sources will result in significant variations in composition and temperature in the Aramis pipeline. A possible large gap between temperatures of the transported CO2-rich stream and the ambience causes a thermal contraction or expansion phenomenon under stagnant conditions. For example, in a situation in which the system is shutdown while the fluid is colder than the ambient temperature, a significant pressure increase can be observed, possibly exceeding the pipeline’s normal operating or design pressures. This pressure increase must be anticipated and managed in both planned and unplanned situations. The equilibrium pressure (also called Settle-Out-Pressure, SOP) and the CO2 phase behavior in these circumstances differ significantly from those observed in hydrocarbon systems. This phenomenon requires special attention for process safety and operating philosophy definition. The lack of industrial benchmarks at Aramis’ scale creates an additional challenge for a safe design. This work describes the flow modeling approach applied to simulate the shutdown operations for this large-scale CO2 transport network. It quantitatively illustrates the relevance of the temperature gradient on the SOP values for different operational scenarios. The main impacts on the operation philosophy and safety engineering design are presented. Moreover, details concerning the simulation methodology, including the selected Equation of State (EoS) and applied safety margin on simulation results, are also presented in this work.

Conventional liposuction techniques involve visible incisions and scars. Newer methods offer less invasive options with improved patient satisfaction and fewer complications. Use of tranexamic acid (TXA) in tumescent solution has shown promise in reducing bleeding and bruising, enhancing postoperative outcomes. The purpose of this study was to describe TXA's effects in edema, ecchymosis, and pain in patients undergoing arm liposuction. A comparative contralateral randomized clinical trial was conducted at a single specialized plastic surgery institution in Bogotá, Colombia, from May of 2022 to February of 2024. The study involved adult patients aged 18 to 60 years undergoing arm liposuction, either alone or in combination with other procedures. Patients received TXA in 1 arm, and placebo in the contralateral arm, with random assignment and blinding for both patients and surgeons. The authors' study included 78 patients, resulting in 156 arms undergoing arm liposuction with either TXA or placebo. Most patients were female (78.2%), with a mean age of 37.6 years and a mean body mass index of 24.7 kg/m². Pain scores and ecchymosis were significantly lower in the TXA arm compared with the placebo arm on the first day after the procedure. No differences in arm circumference measurements were found between groups along the different time points. The overall complication rate was 8.97%. Adding TXA to tumescent solution for arm liposuction significantly reduces pain and bruising, improving patient recovery. Our randomized trial confirms TXA's safety and effectiveness, highlighting its potential as a valuable tool in body contouring procedures and postoperative care.

Abstract Flow induced vibration (FIV) can go undetected in subsea pipework, potentially leading to fatigue failures. Although FIV screening methods have been developed and improved over recent years [1], these are deliberately conservative for multiphase pipe flows and do not accurately quantify the actual fatigue performance of subsea pipework already in situ. The last few years has seen significant development of reliable simulation processes to predict the effects of multiphase flow induced vibration and they have been successfully compared with experimental data for a wide range of operating conditions. However, there is limited in-situ vibration measurement data available from actual operating subsea equipment which would allow a direct verification of the analytical / numerical results. As part of a routine ROV inspection, two spools on an inservice subsea riser tower were observed to be vibrating, and a combined simulation and measurement campaign was engaged upon to quantify the risk of fatigue failure. This paper is focused on the measurement campaign. Based on initial modal Finite Element Analysis, suitable locations were selected for placement of subsea accelerometers. The extracted and processed data, covering almost 2 months of operations, highlighted that the stresses based on the measured vibration were within 35% of the simulation results, and it also showed an unexpected behaviour where the 2 risers interacted with each other; although this was unlikely to cause significant damage. Subsequently mitigations could be evaluated and implemented with confidence utilising a reasonably large safety margin.

Summary In this paper, we clarify the impact of salinity and hardness on partially hydrolyzed polyacrylamide (HPAM) rheology in sandstones with permeability greater than 200 md. For modelers/simulators of polymer flooding, the experimental findings should be of high relevance when projecting HPAM injectivity, fracture initiation, and whether viscoelasticity is significant in oil recovery of capillary-trapped residual oil with or without the presence of fractures. The literature review summarizes the effects of polymer concentration, molecular weight (Mw), rock permeability, and oil saturation on HPAM rheology in sandstones. The experimental work examines HPAM (18–20 million g/mol Mw, 30% degree of hydrolysis) rheology in sandstones with permeabilities ranging from 252 md to 838 md, salinities ranging from 0.1% to 10.5% total dissolved solids (TDS), and hardness levels ranging from 0% to 0.1% calcium chloride (CaCl2). As expected, the magnitude of resistance factors increased with increased HPAM concentration but decreased with increased salinity. The maximum resistance factor in the shear-thickening regime correlated well with C[µ]/(k/ϕ)0.5. The velocity dependence of the rheology (in sandstone) was largely unchanged by salinity between 0.1% and 5% TDS. At 1% TDS, the velocity dependence of rheology (in sandstone) was very weakly dependent on CaCl2 concentration between 0% and 0.1%. We examine the relationship between the onset of shear thickening and the inverse of the polymer solution relaxation time determined from bulk rheological data. The level of mechanical degradation was fairly unaffected by HPAM concentration between 25 ppm and 2,000 ppm [in brine with 1% sodium chloride (NaCl) and 0.05% CaCl2]. These findings should simplify the job of modelers when projecting the performance of polymer flooding.