Day 1 Sun, February 19, 2023最新文献

{"title":"An Integrated Ensemble Based Prediction Approach to Quantify and Propagate Uncertainties of Naturally Fractured Carbonate Reservoirs","authors":"Mohammed Abd-Allah, A. Abdelrahman","doi":"10.2118/213457-ms","DOIUrl":"https://doi.org/10.2118/213457-ms","url":null,"abstract":"\u0000 Naturally fractured reservoirs are holding most of the hydrocarbon proven reserves worldwide. Field development planning and optimization of fractured reservoirs face significant challenges due to fracture system complexity, high reservoir heterogeneity and multiple recovery mechanisms. Fractured systems generally have multiple sets of fractures in different orientations, multiple apertures ranging from tiny fissures to large fracture conduits resulting in complicated fluid flow.\u0000 Reservoir modeling plays a key role in field optimization by examining reservoir recovery under various scenarios. Traditionally, modeling fractured reservoirs is a deterministic process using a single or few reservoirs model (high, mid, and low cases) without proper integration of seismic-to-simulation reservoir model uncertainties. The full span of possible reservoir models and prediction uncertainty isn't captured nor propagated to economics.\u0000 This paper presents an integrated forward modeling workflow using a Synthetic 3D model data mimicking a real North Sea field, where static and dynamic models are tightly connected to integrate the impact of uncertainties at different modeling stages (horizon uncertainties, fault uncertainties, petrophysical uncertainties, discrete fracture network (DFN) uncertainties to dynamic simulation).","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115169484","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effects of Temperature and Rate-Dependent Mud Cake Buildup on Wellbore Stability in Multi-Permeability Formations","authors":"Chao Liu, Dung T. Phan, Y. Abousleiman","doi":"10.2118/213374-ms","DOIUrl":"https://doi.org/10.2118/213374-ms","url":null,"abstract":"\u0000 In this work, we use the theory of multi-porosity multi-permeability porothermoelasticity to derive the analytical solutions of pore pressure and stresses for an inclined wellbore, accounting for a rate-dependent mud cake buildup on the wellbore wall. The solutions are further combined with the Hoek-Brown shear failure criterion and a tensile failure criterion to calculate the critical collapse and fracturing mud weights. We choose a naturally fractured rock formation as an example to demonstrate the coupled effects of temperature, mud cake, and the formation's dual-porosity dual-permeability on wellbore stability. We show that drilling mud with a lower temperature than the rock formation results in differential contraction of the solid and pore fluid constituents and leads to significant alteration of pore pressure and stress distributions. Additionally, a low-permeability and thin mud cake can considerably increase effective tangential stress. Natural fractures also alter the pore pressure and effective stress distributions because of fractures’ higher permeability than the rock matrix. Both wellbore cooling and filter cake buildup decrease the collapse mud weight. Natural fractures have significant weakening effects, increasing the collapse mud weight and decreasing the fracturing mud weight. This work provides the first solutions for wellbore stability analysis, considering together the time-dependent filter cake buildup, thermal effects, and formation's multi-porosity multi-permeability.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"184 7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124917683","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Innovative Coiled Tubing Hybrid Fiber Optics Technology Increases Operational Efficiency","authors":"D. Ahmed, Mohammed Ahmed Kaki, S. Mehmood, Haitham S Saeed Aljuaydi","doi":"10.2118/213739-ms","DOIUrl":"https://doi.org/10.2118/213739-ms","url":null,"abstract":"\u0000 Production logging is very essential to understand the flow profile of the formation that is being produced from. It helps to identify the contribution of the oil, water, and gas to the total fluid. To add, it is done on a usual basis to monitor the reservoir performance. Organic deposit adherence to production logging tool (PLT) spinners can hinder logging operations and result in inconclusive data acquisition. To avoid this problem, standard practices have been developed to clean out organic deposits using a standard coiled tubing (CT) reel followed by production logging using a CT reel equipped with wireline cable. Further optimization of those practices can help minimize operational cost, footprint on location, and overall job time.\u0000 New CT hybrid fiber optic technology (HFOT) was deployed to meet the optimization objectives and eliminate the need for a second CT reel. The technology combines optical fibers and conductor cable with insulation to withstand corrosive fluid environments and deliver power to downhole tools, thereby overcoming prior CT system dependency on downhole batteries to run tools. The system was used in a two-run cleanout-and-logging process: first, organic deposit dissolver was pumped for wellbore conditioning purposes, before production logging was conducted with a multi-spinner production logging tool and pulse neutron tool in the second CT run.\u0000 The new CT HFOT was deployed for the first time in a Middle East reservoir. Organic deposit−dissolving treatments and production logging operations were completed in four oil wells equipped with electrical submersible pumps (ESPs). After stabilizing the pressures and rates, the logging runs were conducted by recording multiple up-down passes and stationary measurements.\u0000 Introduction of the new CT HFOT helped to reduce operational time by an average of 40 hours per job resulting from rig-up time optimization between CT runs, which also helped in delivering a substantial cost saving to the operator. Using one CT reel also helped in minimizing safety risks associated with personnel exposure to heavy lifting equipment during rig-up and risks associated with battery handling and management.\u0000 This study illustrates job design, pretreatment preparation, operational details, and post-job result analysis. It particularly focuses on the HFOT along with a comparison with operations using a conventional CT and CT equipped with wireline cable. Readers will broaden their knowledge by learning about CT cleanout operations, logging operations, and ways in which new technology can optimize overall intervention costs while minimizing location footprint.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125060036","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Salinity and Temperature Effects on Oily Produced Water Treatment Using Polyaluminium Chloride","authors":"Limin Xu, M. Han, Fahd I. Alghunaimi, M. Bataweel","doi":"10.2118/213688-ms","DOIUrl":"https://doi.org/10.2118/213688-ms","url":null,"abstract":"\u0000 Polyaluminium chlorides (PAC) has replaced a large part of traditional aluminous coagulants for water treatment in recent years because of low dosage, high efficiency, low cost and convenient usage. This work studied the effects of salinity and temperature on the efficiency of PAC in removing oil and colloids from oily produced water (PW) and the potential of PAC for high salinity PW treatment.\u0000 Minghua produced water (Di-MHPW) with salinity of 2,815 mg/L and high salinity produced water (HSPW) with salinity of 102,290 mg/L were used in this work. The efficiency of PAC and the optimal dosage were investigated by stability analyzer which allows a step-by-step vertical scanning of the dispersions. The separation time, floc volume and water quality after treatment could be obtained by stability analyzer.\u0000 Transmission intensity was used to evaluate the oil-water separation in PW. High transmission intensity indicates low oil content. Without PAC, HSPW presented faster increase in transmission than low salinity PW indicating poorer stability. The zeta potential of oil drops and colloids in low salinity PW (2,815 mg/L) was −20.4mV. High salinity (102,290 mg/L) increased the zeta potential to −2.2mV, which makes the oil-in-water (O/W) emulsion unstable than low salinity PW. With the addition of PAC, HSPW results in slightly lower transmission with less floc volume. This could be explained by the floc size after the addition of PAC in two PWs. The size of formed floc in HSPW was much smaller than that in MHPW leading to slower separation of floc from aqueous phase and lower transmission intensity. Increasing the temperature enhanced the PAC efficiency in removing oil and suspended solids in both high and low salinity PWs. However, the floc volume also increased especially in Di-MHPW resulting in less water volume. In HSPW, the temperature effect on floc volume was not obvious. Though high salinity reduces the performance of PAC in water treatment, it is still an efficient flocculant for HSPW treatment with high flocculation efficiency, small floc volume and short separation time.\u0000 This work provides the insight of oily produced water treatment using PAC and the effect of salinity and temperature. The results are helpful to develop novel flocculants used for high salinity produced water treatment.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126825454","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Collaborating in the Metaverse for Successful Subsurface Reservoir Characterization","authors":"P. Norlund, D-W.Tsai David","doi":"10.2118/213286-ms","DOIUrl":"https://doi.org/10.2118/213286-ms","url":null,"abstract":"\u0000 With increased pressure on energy companies to reduce costs whilst also planning more complex wells with lower carbon emissions, companies worldwide are always looking for ways to be more efficient & successful in their subsurface reservoir characterization. Improved collaboration across the traditional gaps in the Exploration & Production (E&P) disciplines is an important way to achieve these goals. In this paper, we review the vision of the Metaverse, a fully realized digital world that exists beyond the one in which we live and continues to exist even when we do not interact with it. The Metaverse has some key technological concepts that potentially provide a roadmap to help deliver desired improvements for reservoir characterization collaboration. The first is through an immersive three-dimensional world that can bring together people from remote locations to collaborate in one space. The second is through the realization of a Subsurface Digital Twin. We review where we are and what can be achieved with current technologies using our own research and development as examples, and we postulate on how these technologies will be improved in the immediate future.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116861377","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"From Well to Field: Reservoir Rock Porosity Prediction from Advanced Mud Gas Data Using Machine Learning Methodology","authors":"F. Anifowose, M. Mezghani, Saleh Badawood, Javed Ismail","doi":"10.2118/213339-ms","DOIUrl":"https://doi.org/10.2118/213339-ms","url":null,"abstract":"\u0000 The utility of advanced mud gas (AMG) data has been limited to fluid typing and petrophysical correlations. There is the need to extend the utility to real-time reservoir characterization prior to wireline logging and geological core description. Our first attempt to predict reservoir rock porosity within a well yielded good result. This study improves on the previous effort by utilizing big data obtained from combining various wells in the study area.\u0000 We used machine learning (ML) methodology in the absence of established physical relationship between AMG data, comprising light and heavy flare gas components, and reservoir rock porosity. More than 20,000 data points collected from representative wells were used to prove the concept of predicting the porosity in an interval or section of any well within the study area. Optimized models of artificial neural network (ANN), decision trees (DT) and random forest (RF) were applied to the combined dataset. The combined dataset was randomly split into training and validation subsets in 70:30 ratio. The 30% validation subset simulates a missing well interval or section.\u0000 Comparing the results of the ANN, DT, and RF models using statistical model performance evaluation metrics, the RF model outperformed the others. The RF model gave a training and validation correlation coefficient (R-Squared) values of 0.94 and 0.83 respectively compared to 0.36 and 0.35 for the ANN and 0.84 and 0.73 for the DT models respectively. However, the p-value and mean errors show that the models are statistically acceptable. Having showed in a previous research that a multivariate linear regression model could not handle the complexity in the relationship between porosity and the flare gas components, these results have further confirmed the robustness of nonlinear solutions based on the ML methodology. We conclude that the ML approach to predicting reservoir rock porosity from advanced mud gas data is feasible and better results are achievable with more research.\u0000 This study has confirmed the feasibility of predicting porosity based on a dataset of combined wells and the huge benefit in extending the utility of AMG data beyond the traditional workflows. This approach is capable of complementing existing reservoir characterization processes in assessing reservoir quality at the early stage of exploration. Future work will investigate the impact of integrating the AMG with surface drilling parameters to possibly increase the prediction accuracy.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128985014","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Life Cycle Assessment of Deployment of Liner Hanger vs Long String","authors":"Naeem Minhas, Alexis Davis, Hussain Sharrofna, Sathish Kalaimani, Parvez Khan, Faisal Abdelrahim, Lee Robinson","doi":"10.2118/213318-ms","DOIUrl":"https://doi.org/10.2118/213318-ms","url":null,"abstract":"\u0000 Tackling the global warming challenge by limiting it below 2°C requires serious efforts in reducing the carbon footprint. Oil & Gas industry is one of the major sources of GHG emissions, upstream operations included. There is a major shift in focus to incentivize decarbonization and reduce carbon emissions. Emissions management starts with quantifying the sources of emissions in granularity. This needs quantification and assessment of energy requirements of all the associated activities, from raw materials to manufacturing, transportation, deployment as well as decommissioning and all the intermittent steps in between – a detailed life-cycle assessment. Only then, one can find the opportunities and make informed decisions to reduce overall emissions. In this paper, we describe a method to understand the net environmental impact of deploying Liner-Hanger vs Long Casing String by carrying out life-cycle assessment of both systems across their full value chain, including how and where to make improvements based on carbon assessment specific to greenhouse gas (GHG) Scopes 1 & 2 using ISO standards 14044,14040 and 14067.\u0000 Fulfilment of the net zero commitment by several industrial service companies as well as various customers require identifying sources of the green-house gas emissions as a first step before mitigation and emissions reduction strategies are made and executed. Identification of areas with highest potential for improvement helps in maximising the Return on Investment (ROI) from carbon emissions investment standpoint to make informed decisions.\u0000 Life Cycle Assessment (LCA) tools are used to calculate the greenhouse gas emissions for both the casing deployed with a liner hanger (liner) and long string or casing to surface. Carbon emissions are quantified at every step of the process from raw material, manufacturing, wastage, transportation, assembly to the final stage of deployment in the oil or gas well. All the emissions associated with each step of the process are analysed to find potential areas of improvements from the manufacturing scale to selecting an optimum method for well construction. Effects of localized manufacturing on the carbon footprint is also quantified by making direct comparison between carbon cost of manufacturing in various locations worldwide.\u0000 Detailed Life Cycle Assessment of the two different methods of well construction can help in making informed decisions to select the right method to optimize the process for cost, carbon footprint and safety. It also helps making informed investment decisions on manufacturing plans with the focus on sustainability, efficiency, and cost. Finding the areas with highest potential of carbon footprint reduction makes it easier to target efforts where ROI can be potentially maximized.\u0000 Detailed carbon footprint calculations of both liner hangers and long string deployment along with manufacturing methods have not been carried out before. It will help operators and decision mak","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124585210","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Algorithm for Consistent Mechanical Earth Model Parameters Determination: Applications in Wellbore Stability and Hydraulic Fracturing Modeling","authors":"H. Albahrani, Yara Alkhaldi","doi":"10.2118/213300-ms","DOIUrl":"https://doi.org/10.2118/213300-ms","url":null,"abstract":"\u0000 A mechanical earth models (MEM) is a crucial component of any well design process. Because it describes the subterranean formations in-situ stresses and rock mechanical properties, it is the main input into any geomechanics model. This means high impact issues like wellbore instability, drilling induced fractures, and hydraulic fracturing success probability are all directly dependent on the reliability of the provided MEM. Considering that MEM have been historically developed based on empirical correlations and an expert manual interpretations of logging data, intuitively, their accuracy has a large margin for improvement. Specifically, because the determination of the in-situ maximum horizontal stress is based on manual interpretations of caliper or image logs, the result of this interpretation can vary greatly from one user to the other. Therefore, this work aims to improve this process by presenting an automated algorithm that interprets image and caliper logs data and produce a consistent determination of different MEM parameters.\u0000 The proposed algorithms utilize both resistivity and ultra-sonic based image logs along with wireline caliper measurements to first quantify areas of enlargements or wash-outs within a wellbore section. The algorithms perform this quantification by reading the Red-Green-Blue (RGB) values of each pixel in the image and then assign a radial measurement to that reading. The generated radial measurements are calibrated using the caliper log data. The end result of this process is radial measurements that describe the wellbore dimensions across the 360° range. These radial measurements are then filtered for enlargements by comparing them to the size of the drill bit that was used to drill the hole section being analyzed. Finally, the output from these algorithms is utilized within a stress polygon to determine the in-situ maximum horizontal stress.\u0000 To showcase the value of consistent estimations, MEM produced through the proposed algorithms and an expert manual interpretation are incorporated into geomechanics models. These geomechanics models are intended to issue recommendations regarding wellbore instability while drilling or hydraulic fracturing job design. The comparison between the results of each model are then examined against the outcome of each job in the field. The MEM produced from the algorithms shows higher accuracy when predicting wellbore instabilities and breakdown in hydraulic fracturing job.\u0000 In addition to improving the accuracy of different geomechanics models, the novel method presented in this work also creates a pathway to incorporating information from image logs into sophisticated numerical modeling solutions. It is shown that three-dimensional (3D) geometries interpreted these logs can be incorporated into 3D meshes for the purpose numerical modeling of wellbores through methods like the finite element model.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129903352","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Switched Reluctance Motor Operation Using Three Conductor Electric Submersible Pump Cable","authors":"Robert W. Adams, Jinjiang Xiao, J. Harrist, M. Deffenbaugh","doi":"10.2118/213652-ms","DOIUrl":"https://doi.org/10.2118/213652-ms","url":null,"abstract":"\u0000 Switched reluctance motors have advantages over traditional three phase induction motors for downhole electric submersible pump systems. Controlling an switched reluctance motor systems requires precisely timed waveforms issued from the surface motor controller to the downhole electric motor, which are distorted by the long cabling required between the surface controller and the downhole motor. Additionally, the motor architecture needs to be capable of operation using the existing three-conductor infrastructure available for elecic submersible pumps. A novel surface controller and switched reluctance motor architecture capable of controlling a downhole motor system over long three-conductor cable lengths is developed and demonstrated.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129102253","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimizing Reservoir Pressure Management with Relief Wells During CO2 Storage in Finite Aquifers","authors":"Hassan A. Al Zayer, M. S. Saeed","doi":"10.2118/213558-ms","DOIUrl":"https://doi.org/10.2118/213558-ms","url":null,"abstract":"\u0000 Storing CO2 in deep saline aquifers is a viable technology to manage carbon emissions. However, in finite aquifers, reservoir pressure builds up quickly which can reduce injectivity and limit the ultimate storable quantities of CO2. Therefore, the purpose of this work is to investigate the optimum design for reservoir pressure-management wells during carbon dioxide (CO2) storage in finite aquifers using a numerical simulation method.\u0000 In this paper, a synthetic aquifer model was used to investigate the optimal well placement and geometry, and well spacing to maximize CO2 storable quantities with a less total number of wells. Furthermore, the main target is to maximize the pore volume utilization and target injection rate per well without exceeding the reservoir fracture limit. A fit-for-purpose 3D reservoir simulation model used in this study was built to allow robust and accurate large-scale numerical simulation studies related to CO2 sequestration and storage using synthetic data.\u0000 Multiple CO2 gas injectors were placed at the crest of the structure to utilize most of the available pore volume and maximize the injection rate. Various pressure management schemes were modeled and compared to find out the optimal design which can provide maximum injection rate and ultimate storage capacity. The results showed that well placement depth and the number of active relief wells both are playing a major role in maximizing the ultimate storage efficiency. Since reservoir heterogeneity and anisotropy can significantly affect the relief wells’ design, streamlines tracing can be very helpful to optimize the well spacing and orientation. After 80 years of injection, the simulation sensitivity study showed a significant difference (10-20% of CO2 storage efficiency) between the different pressure management schemes. In conclusion, relief wells are often needed to manage reservoir pressure build-up during CO2 storage in finite aquifers and their design is vital in maximizing the ultimate CO2 storage capacity.\u0000 The outcome of this study is providing a useful guideline to optimize the field development plans and maximize the CO2 storage capacity in finite aquifers.","PeriodicalId":396949,"journal":{"name":"Day 1 Sun, February 19, 2023","volume":"48 6","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113985673","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}