Day 2 Mon, February 20, 2023最新文献

{"title":"Estimation of Missing Molecular Weight and Specific Gravity of Heptane Plus Fraction in PVT Laboratory Report","authors":"M. Al-Marhoun","doi":"10.2118/213430-ms","DOIUrl":"https://doi.org/10.2118/213430-ms","url":null,"abstract":"\u0000 The molecular weight and specific gravity of heptane plus fractions (C7+) are essential in characterizing crude oils. The hydrocarbon analysis of reservoir fluid test usually reports molecular weight and specific gravity of C7+ in the PVT report. Sometimes these values are missing; therefore, estimating them is crucial. This study aims to develop new empirical correlations to estimate the missing molecular weight and specific gravity of the C7+. The experimentally measured hydrocarbon analysis of reservoir fluid tests from the Middle East crudes is the basis for developing the correlations. The input parameters for the correlations are available molecular weight, the specific gravity of C7+, and stock tank oil-specific gravity. The newly developed correlations outperform the existing correlations based on high correlation coefficients and low values of average absolute percent relative error and standard deviation.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 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":"128684714","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":"Multifunctional Cementing Additives, A Way to Improve Rig Time Saving and Annulus Fluid/Gas Migration During Cement Placement","authors":"Francesco Frittella, Auribel Dos Santos, Hussam Jallad, Stephanie Hartanti, Andreas Sundblom","doi":"10.2118/213673-ms","DOIUrl":"https://doi.org/10.2118/213673-ms","url":null,"abstract":"Controlling gas migration in the annular space during cement placement involves several challenges; especially in deep wells where temperature contrast leads to longer wait-on-cement (WOC) time, widening the window where fluids can migrate. Such extended setting is caused by the lower temperature in upper sections which impacts compressive strength build-up while also leads to higher rig time costs. In this paper, the authors focused on key aspects of slurry design to minimize these problems.\u0000 Among the factors that contribute to the invasion and migration of gas and other fluids into the annular space, are insufficient hydrostatic pressure, poor slurry design, inefficient mud removal, problems during cement hydration, or defective cement-formation-casing bonding. For this study, an experimental method was followed to evaluate specific additives and their impact in gas control performance. Different slurry formulations were evaluated at a temperature range between 50°C and 110°C (120°F -230°F) while pressure kept at 5300 psi to minimize variables.\u0000 The laboratory evaluation included tests for determining thickening time, rheology, compressive strength, fluid loss and gas migration. The slurry design involved the use of a novel retarder based on synthetic polymer with carboxylic acid functionality as well as a colloidal silica dispersion. The results showed that the selected additives allowed the slurries to achieve the targeted thickening time with a right-angle set, a short transition time and quick build up in compressive strength. In addition, the migration tests indicated excellent gas control under evaluated conditions. The studied additives performed well individually and even better combined, with a synergistic effect when preventing gas migration and accelerating compressive strength build-up.\u0000 The additives evaluated showed multifunctional attributes that are beneficial not only to prevent gas migration and retard slurry setting, but also to accelerate compressive strength, a cement feature which allows significant savings in rig time costs.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"29 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":"116758232","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":"Exploration of Novel Sacrificial Fluids for Asphaltene Adsorption Remediation","authors":"I. Mohammed, Dhafer B. Alshehri, M. Mohamed, Shahzad Mohammed Kamal, Alade Olalekan Saheed, Sultan Abdullah, S. Patil","doi":"10.2118/213613-ms","DOIUrl":"https://doi.org/10.2118/213613-ms","url":null,"abstract":"\u0000 One of the most extensively studied flow assurance issues in the petroleum industry is the precipitation and deposition of asphaltene. This is in part because of the molecular structure's intricacy and the interconnected elements that influence and regulate its activity. The injection of inhibitors and dispersants, which affect the economics of crude oil production, is now the most successful tactic used. Anywhere throughout the crude oil supply chain, from the reservoir through the tubing and refinery systems, there is an asphaltene concern. However, the area closest to the wellbore, where the greatest pressure decrease is seen, is the most prone to asphaltene adsorption and deposition. Thus, the goal of this study is to investigate how new sacrificial fluids might be used to reduce asphaltene adsorption and deposition around the wellbore. To prevent asphaltene from interacting with the rock surface and shifting the asphaltene problem into the tubing where its impact on wettability is low, the sacrificial fluid/rock ion-specific interactions are investigated.\u0000 This is a groundbreaking attempt to relocate the asphaltene issue from the wellbore into the tubing, where it does not affect the reservoir's wettability. The performance test (adsorption inhibitive capacity), binding energy analysis, adsorption experiments (adsorption affinity, configuration, and mechanism), and fluid characterization (salinity tolerance, surface energy, interfacial tension) of the chosen novel fluids for asphaltene adsorption mitigation are presented. The investigation of ion-specific rock-fluid interactions offers great potential in the search for an effective answer to the asphaltene problem, according to the results. This is proven by the fluids’ levels of binding energy to carbonate rock samples and their capacity to prevent interactions between asphaltene molecules and the rock surface. These studies’ findings open a fresh perspective into the creation of an economical strategy to deal with asphaltene issues and their effects. This study is the first to investigate a long-term fix for wettability changes brought on by asphaltene adsorption on the mineral rock. This entails looking for a fluid that, when used as a remediation fluid in cases of asphaltene deposition, has a stronger affinity for the rock than asphaltene and has the potential to remove asphaltene. Additionally, for the first time in the state of the art of remediation fluid design, realistic environmental conditions are considered in the search for this fluid.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 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":"127449777","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":"Chemical Admixture for Right-Angle Set Wellbore Cements","authors":"Elizabeth Q. Contreras","doi":"10.2118/213736-ms","DOIUrl":"https://doi.org/10.2118/213736-ms","url":null,"abstract":"\u0000 Polyaramid-based chemical admixtures for enhanced gas-tight oil well cements are of interest in the oil and gas industry. Here, a polymer platform is used as the base material for a line of new chemical admixtures in cementing in applications such as small molecule release and particle delivery. Polyaramid-based admixtures provide high-performance for high temperature and high pressure applications in ordinary Portland cement. Experimental results show that a basic cement slurry design responds to the release of admixture by the measure of changes in viscosity and thickening times. Applications in cement design is demonstrated from measurements obtained using oilfield equipment, like the consistometer. Immense efforts towards cement sheath integrity are important for production and safety. Challenges arises during the construction of wells when cement transitions from a slurry into a solid sheath. This transition can span over a significant length of time allowing gases to travel to the surface, causing casing-in-casing (CCA) events and pressure buildup. The ideal scenario is to eliminate the transition time of the slurry by designing cements to set instantaneously into an impermeable sheath. Right-angle set cements are characterized by a 90° set time as measured by a consistometer. The consistency of cement after addition of this new admixture remains at 20 Bc. In all cases, the admixture thereafter remains embedded within set cement and contributes significantly to its mechanical property. Dual performance stems from unique characteristics, such as chemical composition and mechanical integrity of new polymer admixtures. Using these admixtures, gas-tight cement sheaths show enhanced mechanical properties, such as resistance to breakage and fracture propagation, as well.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"20 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":"125948927","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":"Transforming a Mechanical Vertical Drilling Tool into a Digitally Controlled Rotary Steerable Tool - The Journey of Design, Development, Testing and Commercialization","authors":"Steve Jones, J. Sugiura","doi":"10.2118/213707-ms","DOIUrl":"https://doi.org/10.2118/213707-ms","url":null,"abstract":"\u0000 The design and development of a rotary steerable system from inception to commercialization, with proven performance/reliability recognition is an engineering challenge to say the least. Rotary steerable systems (RSS) are one of the most challenging drilling tools to bring successfully to the market. This is because they combine mechanics, electronics and hydraulics that all must operate together to make the system work.\u0000 With the complex task and cost of bringing multiple engineering disciplines together on one team (mechanical, electrical, electronic, embedded code, software and test engineers) to develop a rotary steerable, it is often a challenge for a small private company to start from the ground up. In this instance, a completely different approach was adopted to bring a unique RSS to the market.\u0000 Utilizing an existing mud operated mechanical vertical drilling tool with slow rotating steering head, the engineering team set to work to develop an electronic control unit with a digital mud valve to transform the tool into a cost-effective rotary steerable tool.\u0000 The design, development, engineering challenges, in-house and field-test program will be described to show how rotary steerable development on a budget is possible. Maintaining a tight project budget leads to engineering creativity and thought paths that cannot be inspired when large budgets are subsidizing product development.\u0000 The paper will detail how the rotary steerable product was successfully tested by partnering with operators in North America land. Selecting some of the harshest drilling areas for testing increased the pace of development, and improvement was accelerated with the use of multiple drilling dynamics sensors and pressure sensors.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"106 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":"128109123","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":"Prediction of Slug Length for High Pressure Gas/Liquid Two-Phase Flow in Horizontal and Slightly Inclined Pipes","authors":"Eissa M. Al-Safran, A. Aql","doi":"10.2118/213727-ms","DOIUrl":"https://doi.org/10.2118/213727-ms","url":null,"abstract":"\u0000 Slug flow in pipelines is the most common flow pattern. Slug length is crucial characteristic for pipeline and downstream separation facility design and operation. In addition, mechanistic two- phase flow models require slug length as closure relationship to solve for pressure gradient and average liquid holdup in slug flow. However, the existing slug length closure relationships developed for low pressure are found to poorly perform in high-pressure conditions, i.e. high gas- to-liquid density ratio high, resulting in high uncertainty predictions of slug length, pressure gradient and liquid holdup. This work aims to propose a mechanistic slug length model and to identify the optimal closure relationship for high-pressure condition through error minimization technique using Genetic Algorithm. In addition, the identified set of closure relationships are found to match the physics of slug flow under the investigated conditions. As a result, the proposed model result in a coefficient of determination R2 = 0.85 and an Absolute Average Error (AAE) approximately equals 70% outperforming the best-performing exiting model in the literature.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"18 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":"126747998","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":"Successful Application of a Novel High-Pressure High-Temperature (HPHT) Quartz Crystal Microbalance (QCM) Set-Up to the Evaluation of Asphaltene Deposition Inhibitors","authors":"Abeer Ghaffoori, Ross Anderson, M. Hoopanah, B. Tohidi","doi":"10.2118/213750-ms","DOIUrl":"https://doi.org/10.2118/213750-ms","url":null,"abstract":"\u0000 Asphaltene deposition is a major flow assurance challenge in oil production. Changes in fluid temperature, composition, and particularly pressure, can all lead to solid asphaltene precipitation. This may deposit in the formation, wellbore, or production lines, causing reduced flow or even complete blockage. The objective of this work was to evaluate a recently developed, novel high-pressure high-temperature (HPHT) quartz crystal microbalance (QCM) set-up for the testing of asphaltene deposition inhibitors.\u0000 Developed within a joint industry project (JIP) aimed at improved asphaltene inhibitor testing and deposition modelling, the variable volume (50 to 450 ml), HPHT QCM set-up can operate at pressures up to 410 bar (6,000 psi, extendable to 690 bar / 10,000 psi), allowing measurements on live oil / re-livened oil (dead oil made live again by gas addition) systems for real production pressure-temperature (PT) conditions / scenarios. In this work, the HPHT set-up has been used to evaluate several commercial asphaltene inhibitors for two re-livened oil systems in terms of AOP pressure and relative mass asphaltenes deposited versus blank (inhibitor-free) cases. For comparison, traditional heptane titration tests were also carried out for the same dead oil ± inhibitor systems using an atmospheric QCM apparatus.\u0000 Results demonstrate the HPHT QCM to be a very promising tool for asphaltene inhibitor evaluation, with clear variations in anti-deposition performance seen for different chemicals. Furthermore, while findings show that atmospheric pressure dead oil titration results often agree well with those for re-livened HPHT tests, there are significant differences for some inhibitors, meaning the former may not always be representative of real conditions, while the latter should presumably be more so. These observed differences may go some way to explain problematic discrepancies between traditional laboratory test approach results and real-field chemical treatment performance, i.e., where an inhibitor performs well in the laboratory, but not in the field.\u0000 The reported HPHT QCM approach is novel in that it can be used to investigate asphaltene inhibitor performance for live / re-livened fluids for real production PT conditions/scenarios.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 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":"130375029","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":"First Successful 16 X 13.375-in. Casing-While-Drilling Operation in Kuwait Saves 27 Rig Days and Reduces Well Delivery Time","authors":"Saleh Muqeem, Mohammed Al-Mulaifi, Yasser Al-Assil, Anish Sekhri, Mai Yacoub Sulaiman, Chandra Shekhar, I. Abdelrahman, Talal Abdulkareem, Ayomarz Homi Jokhi, Mahmoud El Kady, Naser Al Saad, Shahad Al Muzaini, Fatemah Mataqi, Saad Al Harbi, Naser Al Kanderi, D. Herrera, J. Halma, Sameh Ibrahim, Biju James","doi":"10.2118/213628-ms","DOIUrl":"https://doi.org/10.2118/213628-ms","url":null,"abstract":"\u0000 Drilling the 16-in. section in Minagish field wells in western Kuwait is among the most challenging well sections. Challenges include drilling through severe loss conditions, destabilized shale, and deteriorating hole conditions. These conditions can result in hole collapse or lost in hole of the drill string that requires sidetracking. The objective of project presented in this paper was to develop an engineered solution to drill through the difficult zones, lessen nonproductive time, and reduce the total well cost.\u0000 The solution proposed was to use casing-while-drilling technology with a drillable bit and drill through the fractured dolomitic limestone and sandstone formation while simultaneously setting casing. The drillable casing-while-drilling bit was specifically designed and engineered to conform to the formations in the field. The drillable casing-while-drilling bit is manufactured with a material that can be drilled out with either conventional roller cone or fixed cutter bits. A plastering process was used, which smears the cuttings generated by drilling against the borehole wall, seals the pores or fractures in the formation, and helps reduce fluid losses while maintaining well integrity.\u0000 The first successful 16 × 13.375-in. casing-while-drilling job in Minagish field reduced well delivery time for the operator and saved 27 rig days with substantial savings in the total well cost. The section was drilled successfully while encountering total mud losses through fractured dolomitic limestone and sandstone formations. Continued drilling managed to reduce losses with 30 to 50% returns and reached the target depth. Preventing the risk of losing the bottomhole assembly in the hole and alleviating the use of multiple cement plugs saved additional cost for loss-cure plugs to heal the loss-prone formations. After reaching the target depth, cementing, pressure testing of the casing, and drillout of the drillable casing-while-drilling bit using a rerun fixed cutter bit were performed successfully.\u0000 On an average, eight wells are drilled per year in this field. With the successful implementation and the savings obtained by using this casing-while-drilling technology in the first test well, there is the potential for substantial annual cost savings, help the operator deliver wells in less time, and eventually increase production by increasing the number of wells drilled per year.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"38 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":"134440347","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":"Successful Deployment of First One Trip Integrated Full-Bore Off-Bottom Cemented Closed System ICD Screens Completion","authors":"Q. Looni, Malik. M Humood, Syed Abu Faizal, Abdullah Al-Muzayen","doi":"10.2118/213535-ms","DOIUrl":"https://doi.org/10.2118/213535-ms","url":null,"abstract":"\u0000 Conventional Off-bottom Cemented (OBC) application with Inflow Control Device (ICD) presents several challenges for well completion operations. Operational and HSE risks, complexity of deployment with several hydraulic activated tools, excessive operational time, and associated costs being some of them. This paper presents first successful deployment of a new generation integrated off-bottom cemented closed system ICD completion installed in a challenging offshore sandstone environment in Middle East with proper engineering, HSE risks were reduced while saving considerable rig time compared to the conventional system.\u0000 To address the challenges posed by OBC with ICDs application a new system consisting of full-bore closed system ICD screens, full-bore mechanical open hole packers and a fit for purpose dual opening pressure activated cementing valve (DPACV) were developed. The system allows for installation of ICD screens and zonal isolation open hole (OH) packers with off-bottom cemented completion in one-trip with no dedicated work string run to set OH packers. Furthermore, the full-bore access allows drill-out of cement/plug and drifting lower completion in one clean-out run with 3.875\" OD/ gauge bit, which was previously performed in two separate runs due to size limitations. The system brings significant cost-savings, reduced rig time, and expedited well delivery. This system also allows for reduced wellbore exposure time, more efficient displacement rates/volumes for dissolving filter cake, with better production ID and easier future well interventions.\u0000 The new system was deployed in a critical re-entry horizontal well in a sandstone reservoir. The objective of the completion was to isolate non-reservoir section and an active gas cap below the kick-off window with off-bottom cemented liner and completing the reservoir section with ICD sand screens and open hole packers. The challenge in deployment was due to unstable hole conditions, active shale & possible wash outs sections. The performance of the new system was evaluated by comparing it to a conventional system installed in the same field.\u0000 The off-bottom cemented ICD system was successfully deployed to target depth in challenging open hole conditions. The activation of all tools and the off-bottom cement job went as per plan. Performance comparison showed that the new system was completed 42% more efficiently than the standard conventional completion deployment time, saving significant rig time and cost. The most time saved was achieved by eliminating tripping in and out with wash pipe for setting the OH packers. Drill out of cement/plug and drifting of the lower completion was done in a single cleanout trip compared to two separate trips in a conventional system. Post completion, production and noise logging confirmed positive isolation of the gas cap from the reservoir section, confirming all packers sealing integrity, and the production log confirmed inflow from all ICD compartment","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"42 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":"130192255","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":"Characterizing Movable and Non-Movable Zones in a Mature Carbonate Reservoir: A Novel Workflow Using Resistivity Logs","authors":"S. Al-Otaibi, Saud Aldajani, Talal Al-Sayyar, Salem S. Al-Marri","doi":"10.2118/213405-ms","DOIUrl":"https://doi.org/10.2118/213405-ms","url":null,"abstract":"\u0000 Optimizing reservoir recovery depends on an in-depth understanding of natural geological complexity to predict reservoir behavior. Understanding the difference between producible oil and non-movable oil zones is important, which will aid in the refinement of the design of future wells.\u0000 During the mature life cycle of the Maastrichtian carbonate reservoir, it was observed that some wells would not perform optimally, while others would experience a significant drop in production. By analyzing petrophysical and production data, the reservoir was found to contain hydrocarbons consisting primarily of heavy oil and stringers of light oil. Based on reservoir characterization and after assessing the production profile to understand the hydrocarbon behavior, this study was performed to identify and distinguish movable oil zones from non-movable oil zones.\u0000 Conventionally, expensive intervention methods, such as running modular dynamics formation tester (MDT), nuclear magnetic resonance (NMR) logs, and production logging tools (PLT), are used to determine the oil viscosity (API) and identify contribution zones from the entire hydrocarbon interval. However, using these methods results in increased operational costs and reduced production.\u0000 This study proposes an alternative approach using resistivity logs to identify and distinguish between movable and non-movable hydrocarbon zones to improve reservoir management. The concept behind this method depends on the resistivity logs validated using MDT and PLT data. A shallow resistivity reading higher than a deep resistivity reading indicates that hydrocarbons were not flushed (unmoved) by invasion. Thus, the zone contains unproducible hydrocarbon reserves. The resistivity cut-off value was estimated based on the PLT and MDT data to identify movable oil intervals.\u0000 In all the wells analyzed, there was a good correlation among the calculated zone thickness, core data, sampling data, and mud logs. Dielectric logs were run in a couple of key wells, which enabled the Sxo estimation independent of resistivity. Additionally, the Sxo obtained supports the fluid interpretation. Productive zones were accurately identified for each well, and recompletions were made to produce from these bypassed opportunities.\u0000 The proposed method is robust with respect to environmental corrections, not contingent on MDT, NMR, and PLT knowledge, and can be carried out without halting production.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"8 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":"115042522","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}