Day 2 Wed, January 25, 2023最新文献

{"title":"Water Based Mud High-Resolution Resistivity Images, Innovated Operational Practices to Enhance Log Quality in Lateral Boreholes Drilled with Multiple Fluid Systems.","authors":"A. Mohamed, Mandefro B Woldeamanuel, M. Gouda, Hesham Rashad","doi":"10.2118/212660-ms","DOIUrl":"https://doi.org/10.2118/212660-ms","url":null,"abstract":"\u0000 Understanding how natural fractures are behaving is providing a growing knowledge about reservoir's structures and stresses, hence it becomes important to deploy high-resolution resistivity imaging service, especially in case of severe drilling fluid losses. In lateral boreholes, deployment of such service comes with its known additional operational challenges. In certain cases, drilling of these laterals starts with oil-based mud (OBM) to achieve certain objectives, then displacement with water-based mud (WBM) takes place when mud losses encountered at certain depth while drilling. Recording these sensitive measurements in such environment requires special planning for the string configuration and logging parameters optimization, and this article is explaining innovative operational practices followed to acquire high-quality image logs, and it will go through different scenarios while highlighting the potential constraints and limitations.\u0000 Firstly, it is important to identify how long the borehole interval is drilled with OBM before displacement operations, as this controls the borehole conditioning process after TD and before pull-out-of-hole (POOH) for pipe-conveyed logging (PCL). It depends, so the situation is being assessed and discussed to decide the feasibility of logging operations. Afterwards, decision comes to either cancel the service request if it is confirmed that quality of data is expected to be highly degraded, or to proceed with logging operations if log quality is anticipated to be acceptable and meeting the deployment objective(s). With the latter option, clear plan of borehole conditioning procedures will be prepared, while considering an optimized tool's acquisition parameters in such mixed and challenging borehole environment.\u0000 Different scenarios of complex mud environments were tested, including one case with variable WBM salinities across the logged MD interval without having any interference from any OBM during the drilling process. General conclusion is that less interval drilled with OBM pours into the benefit of obtaining higher data quality from WBM resistivity imager after less borehole conditioning time. In certain cases when longer interval was drilled with OBM, different treatment and conditioning processes resulted in accepted WBM resistivity imagers data quality. These practices of real tested cases are not granting accepted images quality all the way because of different variables like mixed fluids additives and salinities as well as borehole wall exposure time to such conditions, but they are providing sufficient awareness about how and when to expect an accepted image quality. To illustrate this conclusion, this article will also present a case where performed treatments and borehole conditioning processes were insufficient and had never produced any accepted image quality at all, which gives an insight that anticipated images quality in such scenario is considerably poor, and where to set valid cutoffs ","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116679713","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":"CO2 Sequestration in a Limited-Data Depleted Gas Reservoir for Reservoir Capacity Assessment and Injection Optimization - Case Study","authors":"Michael Nashaat Kaldas, Bryan Saunders, A. Nasiri, Stacia Barben","doi":"10.2118/212661-ms","DOIUrl":"https://doi.org/10.2118/212661-ms","url":null,"abstract":"\u0000 Greenhouse gases are a big risk to our life on the planet, as they absorb the infrared radiation which results in trapping the heat in the atmosphere and making our planet warmer. Carbon dioxide (CO2) is one of the key and major greenhouse gases that are emitted by humans. Some of these gases occur naturally in the atmosphere, but human activities have changed their concentrations. As per the U.S. Environmental Protection Agency, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2020 \"From the pre-industrial era (i.e., ending about 1750) to 2020, concentrations of these greenhouse gases have increased globally by 47.9, 168.4, and 23.3 percent, respectively (IPCC 2013; NOAA/ESRL 2022a, 2022b, 2022c)\".\u0000 There are different sources of CO2 emissions as will be mentioned later. Carbon capture and sequestration (CCS) technologies are considered a practical option to protect the atmosphere from these emissions. This is done through capturing the CO2 from its sources, transporting it to the injection location and then sequestrate it into deep formations. This CO2 could be injected in saline aquifers or depleted oil and gas reservoirs for storing purposes or it could be injected in producing oil and gas reservoirs for enhanced oil and gas recovery respectively. From the subsurface perspective, there are three key parameters that needs to be considered in the selection of any reservoir:\u0000 Storage Capacity Storage Containment CO2 Injectivity\u0000 This paper is a case study of CO2 sequestration in a depleted gas condensate reservoir that was produced down to abandonment pressure. The objective of the project was to deliver a detailed site characterization and reservoir simulation for a Carbon Sequestration program for Castex Energy in Louisiana. Castex Energy is pursuing the development of a CO2 injection hub to support permanent geological sequestration with CO2 supplied from third party sources in the southern Louisiana area. The CCS project will utilize acreage from a depleted gas reservoir in state waters in southern Louisiana.\u0000 The ultimate objective of this phase of the project is to create a geological model and conduct preliminary reservoir simulations that will be required for Class VI permit to construct the applications. This has been implemented through the following key tasks:\u0000 Building the static model and generate several realizations for the static properties (Facies, Porosity and Permeability): this was a key step to come up with many realizations to capture the static model data uncertainty. Implementing P/Z analysis to have a good understanding about the initial gas in place History matching though tuning the model by combining the static and dynamic uncertain parameters Evaluating the reservoir storage capacity and optimizing the CO2 injection performance and plume movement\u0000 The model was a very powerful tool to quantify the reservoir storage capacity and to have a good understanding about the CO2 injectivity and plume movement in t","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"406 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127596343","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":"Success in Complex Channel Sand Reservoir Development Driven by New Generation of Ultra-High-Definition Multilayer Mapping-While-Drilling Service and Hybrid Rotary Steerable System","authors":"Bin Yang, Tong Li, Fei Wang, Feng-Yuan Wang, Shu Zhong Li, Kai Wu, Zhongtiang Hu, Li Wang, Yao Chen, Qi Xun Liu, Yan Xing Zhang, J. Maalouf","doi":"10.2118/212686-ms","DOIUrl":"https://doi.org/10.2118/212686-ms","url":null,"abstract":"\u0000 Accurate real-time characterization of complex channel sand reservoir is very critical for horizontal well drilling and production improvement. CB block located in the southwest part of Bohai Bay which is the main offshore block for SINOPEC Sheng Li. This block is featured by braided river and fluvial deposition environment. The operator faced challenges during horizontal drilling, such as thin sand channels, inner-beds development, severe lateral change, unstable sand structure and low sand connectivity.\u0000 A horizontal well drilling campaign was launched in 2021. Through considerable data assessment and feasibility study, the new generation of Ultra-High-Definition multilayer mapping-while-drilling service and rotary steerable system (RSS) as an integrated solution package was deployed to this project to overcome above challenges. Without any a-priori assumptions, the new generation service doubles depth of detection (DOD) range compared with previous bed-boundary detection services, delivers clearer boundary delineation, and is capable of remotely identifying the quantitative subsurface features, including layers’ numbers, resistivity and anisotropy distribution, thickness, and dip etc. Meanwhile, the truly hybrid RSS with near bit measurements ensures accurate and smooth trajectory control and reduces the drilling risk in the soft formation.\u0000 The pilot project was successfully completed. With the help from real-time measurements combined with seismic data, and by utilizing the advanced inversion advantage, this technology could depict whole individual sand bodies and their mutual lateral contact relationship clearly, which not only can optimize the reservoir exposure rate but also provide a better way for detailed reservoir characterization. Four wells were geosteered for a total of1026m with 96.1% reservoir exposure rate. Primary production from these 4 horizontal wells exceeded the expected production by 40% with only 10% water cut.\u0000 This innovative solution demonstrates its advantage on optimizing a complex channel sand drilling and development. The authors believe that the fit-for-purpose solution could be expanded to other similar projects by showcasing the distinctive case studies in this paper.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128103409","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":"Single Well Chemical Tracer Application for Chemical EOR Pilot Project: Principles and Best Practices","authors":"A. Khanifar, Arif Azhan Abdul Manap","doi":"10.2118/212590-ms","DOIUrl":"https://doi.org/10.2118/212590-ms","url":null,"abstract":"\u0000 Chemical injection has been emerged to be one of the processes that can improve oil recovery from major Malaysian offshore oilfield which is currently under waterflooding. Alkali-surfactant (AS) process was identified to be an optimized chemical system for this application. The chemical recipe and formulation for the field trial tests were obtained from comprehensive laboratory experiments studies. Pilot tests were designed and executed to evaluate the effectiveness of this chemical injection prior full field-scale implementation.\u0000 Single well chemical tracer (SWCT) technique has been utilized to determine the residual oil saturation (Sor) before and after chemical injection in a one-spot pilot and cost-effective manner approach. Two wells and two different chemical formulations were investigated for AS injection responses and four tests were conducted in sequence. The objectives were to validate the laboratory results, assess the critical chemical process parameters such as Sor reduction, adsorption, injectivity, and obtain an operating experience at a harsh offshore environment with high reservoir temperature. Sea water treatment and softening process was needed to protect chemical slug from high-salinity and high-hardness environment.\u0000 Favorable results achieve where successfully mobilized substantial amounts of Sor, chemicals easily mixed with no injection problems encountered, and no measurable dilution effects that indicated fluids travelling outside of test zones. The initial Sor waterflooding observe to be 0.16 and 0.27 for well 1 and well 2 respectively, while, interestingly, both wells show a 0.04 increase in Sor after first pilots were completed. It is most likely due to a shift in rock wettability toward more water wet. Competing reactions of alkaline was a major concern. Pre-flush and post-flush buffer of soft water was designed to minimize these reactions and allow surfactant to work in more favorable lower salinity water. Fortunately, Sor results show that the competing reactions were not severe enough to prevent the AS systems from working. The lowest Sor were 0.06 and 0.08 in the case of 1.5 PV and 1.0 PV soft-water buffer, respectively. It shows that Sor was not significantly reduced with additional 50% PV buffer. Even in the case of 0.15 PV buffer and 23,000 ppm salinity, Sor decreases only by 25%. It demonstrates that some degree of success will be gained even in the worst case where the salinity was reduced by 60%.\u0000 This paper presents the principals of SWCT pilot application for a chemical EOR (CEOR) project case study and share the best practices and lessons learnt were achieved from these field trail tests. This paper can be used as a technical reference and guideline for upcoming CEOR projects and promote a detailed development plan which can potentially address various challenges that are often encountered in implementing chemical flooding, particularly at offshore oilfields.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130066937","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":"A Numerical Study of Mineral Dissolution in Deep Heterogeneous Carbonate Reservoirs: Implications for CO2 Geo-sequestration","authors":"A. Fathy, M. Arif, A. Adila, A. Raza, Mohamed Mahmoud","doi":"10.2118/212632-ms","DOIUrl":"https://doi.org/10.2118/212632-ms","url":null,"abstract":"\u0000 CO2 geo-sequestration has shown potential to mitigate global warming caused by anthropogenic CO2 emissions. In this context, CO2 can be immobilized in subsurface formations due to chemical dissolution/precipitation via mineral trapping. However, long-term mineralization involves interdependent complexity of dissolution and precipitation kinetics. In this study, a numerical approach is developed and implemented to analyze the effect of rock type, reservoir temperature, brine salinity on CO2 mineral trapping in compositionally distinct subsurface carbonate reservoirs.\u0000 Here, we simulated field-scale models for three different subsurface reservoirs’ compositions (calcite, dolomite, and siderite) to assess the mineral trapping capacity. The base case of a 3D carbonate formation was created. The petrophysical parameters were then upscaled (Sw, Sg, K, and φ) to capture the subsurface conditions. Subsequently, CO2 mineral trapping capacity was computed for different rock compositions mimicking carbonate/brine/CO2 systems. Moreover, the CO2 geo-storage potential was assessed under reservoir temperature, salinity, storage duration, and cumulative injected CO2.\u0000 The effect of reservoir mineralogy was analyzed via the amount of CO2 mineralized within 100 years of storage duration following 2 years of injection as a base case. The results revealed significant variation in storage capacity as the mineral type changed. In particular, 100% calcite surface showed the highest CO2 storage capacity compared to both dolomite and siderite. The results could be attributed to the distinction of each mineral in terms of its relative cations dissolve-out rate. Moreover, increasing the reservoir temperature resulted in a monotonic increase in mineralization potential with an insignificant increase in case of siderite. Notably, calcite outperformed both siderite and dolomite as a preferable medium for CO2 mineralization as the injection duration increased over both 100 and 200 years of storage. Additionally, the increase in salinity either significantly decreased the amount of CO2 mineralized in case of calcite and siderite or showed no effect at all in case of dolomite.\u0000 This work provides a new insight for underpinning the effects of carbonate reservoir composition on CO2 mineral trapping capacity which has not been investigated much. Overall, the results showed that CO2 trapping in subsurface carbonates immobilized CO2 for a long-term stable geo-storage.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130898691","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":"A Detail Study Evaluating the Impact of Downhole and Wellhead Compression to Optimize Production From Gas Wells with Liquid Loading Issue: An ADNOC Onshore Gas Field Case Study","authors":"B. Bernadi, Mahmoud M. Douglas, Alia Belal Zuwaid Belal Al Shamsi, Fatima Omar Alawadhi, Ihab Nabil Mohamed, Mariam Ahmed Hosani, Ahmed Mohamed Al Bairaq, A. Abdullayev, Allen Roopal","doi":"10.2118/212677-ms","DOIUrl":"https://doi.org/10.2118/212677-ms","url":null,"abstract":"\u0000 An onshore retrograde gas field in Abu Dhabi has several wells with severe liquid loading issue as reflected by low intermittent production rates. To overcome this, a study was performed by looking at the effectiveness of downhole and wellhead compression and their impact on the production rates. Utilizing IAM, the benefit will not only be seen at the well level but also at the field scale with the ultimate goal to increase the Recovery Factor.\u0000 The study was started by identifying the wells suffering from liquid loading issue. The wells were then ranked according to the severity of the problem based on the GLR values. Hence, the top 2 wells were prioritized as the candidates. Both the downhole and wellhead compressors were then modelled in IAM and several sensitivity runs were performed to evaluate the optimum compressor settings to see the impact on flow stabilization and wells productivity. The selected best scenarios were also compared with the base case as reference where no intervention was performed at all (natural flow).\u0000 The study reveals that both downhole and wellhead compression can give wells flowrate stability with substantial improvement on the production rates for longer duration of time compared to the base case scenario. More than that, the downhole compression shows better gain for production rates compared to the wellhead compression. This is mainly attributed to the fact that gas density is higher at the bottom of the well than at the surface and since the mass flow rate depends on the density of the gas and the volumetric flow rate, this will lead to higher mass flow rate for the same volumetric flow. Consequently, a downhole compressor will produce more fluid quantity rather than a wellhead compressor.\u0000 The study clearly demonstrates and evaluates the effectiveness of downhole and wellhead compressors to mitigate liquid loading inclusively to improve gas wells production. By utilizing IAM that is capable to capture the interactions between subsurface to surface network elements, the improvements on wells deliverability after implementing downhole and/or wellhead compression can be accounted more accurately taking into account more complex production operations with the ultimate goal to maximize the field Recovery Factor.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125846361","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":"A Novel Semi-Supervised Clustering Method for Carbonate Pore Size Distribution in Middle East Using Earth Mover Distance","authors":"Ruicheng Ma, D. Hu, Zeqi Zhao, Yong Li, Yixuan Zhao, Fei Gu, Yu-ning Wang","doi":"10.2118/212593-ms","DOIUrl":"https://doi.org/10.2118/212593-ms","url":null,"abstract":"\u0000 Pore space texture and its pore size distribution are critical parameters for displacement efficiency for waterflood, which have been applied in Middle East. For sandstone, pore size is a log-normal distribution usually. However, when it comes to carbonate reservoir, complex sedimentary and diagenesis yield complex pore size distributions including unimodal, bimodal and multimodal distribution. Therefore, it is not reasonable to classify different pore size distribution through statistic parameters such as mean, standard deviation, skewness and kurtosis. It is essential to propose a novel method to classify numerous pore size distribution results accurately and automatically by curve shape. This paper proposes the application of earth mover's distance (EMD) to pore size distribution, which is not mentioned before. The automatic clustering method is efficient and accurate to process massive data. Therefore, this method can prompt to systematic analysis and research of a giant scenario of reservoir injection characteristics in Middle East.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124728701","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":"Improved Reservoir Characterization of Tight Carbonate Rocks using Multiple High-Resolution Logging While Drilling Technologies for Completion and Stimulation Optimization with Fishbone Technologies; A Case Study from Offshore Abu Dhabi","authors":"Sundos Al Abed, H. Khemissa, Susumu Kurokawa, A. Aki, W. Fares, Muhammed Mubeen, W. Chehabi","doi":"10.2118/212662-ms","DOIUrl":"https://doi.org/10.2118/212662-ms","url":null,"abstract":"\u0000 Objective of this real case study was to test new technology of stimulation in tight rock along the horizontal drain. The reservoir architecture corresponds to stacked zones interbeded of porous and dense rocks. The dense ensure a vertical seal between the reservoir zones. The thickness of theses layers are varing from an area to other. Stylolite and feaw fractures were mapped and occurred maily in the dense zones. The study showed that the fractures are bded confined and very rarely they put incommunication two porous zones.\u0000 The targeted reservoir lithology is predominantly limestone with variable percentages of dolomite (20 to more than 50%), exhibiting laterally variable micro to miso pore texture. Saturation calculations using conventional open hole logs data shows high uncertainty associated to quantifying movable from bounded fluid and their type.\u0000 A new real-time petrophysical data acquisition program, using Logging While Drilling (LWD) technologies, is implemented in this case study to estimate the proportion of connate and free fluid distributions along a horizontal well section and to predict permeability, to help decide for depth of perforation for stimulation and optimize lower completion design.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127443899","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":"A Data Driven P-V-T Model to Predict the Oil Formation Volume Factor, Solution GOR and Bubble Point Pressure for Characterizing an Oil Reservoir","authors":"Saket Kumar, Sandarbh Gautam, Nitu Kumari Thakur, Murtaza Ahmed Khan, Sikandar Kumar","doi":"10.2118/212600-ms","DOIUrl":"https://doi.org/10.2118/212600-ms","url":null,"abstract":"\u0000 Characterizing an oil reservoir requires one to understand the Pressure- Volume-Temperature (PVT) properties of reservoir fluids, especially bubble point pressure, solution gas oil ratio and oil formation volume factor because of its more often utilization in reservoir engineering studies. The current correlations are restricted by the use of sample from a particular field. As the physical properties and the composition of the crude oil varies the results becomes erroneous after a specific range. This correlation will give results only over a specific range of properties like specific gravity, viscosity, composition etc. The challenge is to develop a new approach which overcomes the current shortcomings. In this paper a new machine learning based model has been developed using Interactive Multivariate Linear Regression (I-MLR) method by integrating a large number of datasets to predict above mentioned properties. It overcomes the restriction of the previous correlations as it does not use data from any particular field. As such it is applicable over wide range of physical properties and composition. This model does not require any laboratory studies which makes it more economical. The validation of the model is done after detailed comparative study done with various commercially used empirical correlations.","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125459509","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":"Vertical Interference Testing as a Gateway to Permeability Anisotropy Demystification and Understanding Fluid Displacement in Carbonates","authors":"V. Pandey, Permanand Dhermeshwar Thankur, Setiyo Pamungkas, T. Thomas, Redha Al- Lawatia, M. Samir, T. Zubair, Abdul Bari","doi":"10.2118/212646-ms","DOIUrl":"https://doi.org/10.2118/212646-ms","url":null,"abstract":"\u0000 Carbonates are infamous for their complex intrinsic heterogeneity, exaggerated due to stratification and layered geology. Characterization and correlation of this heterogeneity with recovery mechanisms becomes critical pertaining to Lower Cretaceous reservoir ‘A’ with over 4 decades of production/injection history. Hence, it is pertinent to systematically reduce the uncertainties associated with reservoir characterization by delineating high permeability streaks, permeability-contrasts, links between geological and petrophysical facies and their impact on field scale production/injection strategies.\u0000 Emphasis was put on capturing downhole dynamic Kv/Kh profile across sub layers of the reservoir ‘A’, to enable assignment of representative values into reservoir simulation model with associated reservoir zonation. Vertical interference testing (VIT) was designed in a crestal location well with a history of near-by waterflooding, integrating simulator-based outputs with petrophysical and borehole image logs of an offset. Drawdown-buildup cycle was performed across source probe or packer, while simultaneous monitoring of pressure at observation probe. To reduce uncertainty and incorporate statistical sense into the data, multiple cycles of drawdown-buildup were conducted for vertical connectivity evaluation.\u0000 In total, eleven VIT tests conducted with formation tester tool utilizing dual-straddle-packer and two-probe modules were interpreted implementing a systematic approach considering vertical communication as a function of geological facies and textural aspects from borehole images, geological information on fractures/faults, and surfaces. Interpretation involves identification of flow-units based on available logs, followed by identification of flow regimes (spherical/radial) to history-match data for estimation of horizontal and vertical permeabilities of each layer. Resultant analysis yielded insights on anisotropy by validating vertical communication through stylolite and across dense layers. Integration of VIT analysis results (Kh,Kv,Kv/Kh) with petrophysical logs led to the establishment of water flood advancement mechanism in this observation well at the crestal location of field. This establishes a critical link between integrated geological, textural and facies analysis in context of sedimentology, layering and rock quantified fabric permeability indicators visible on high vertical and horizontal resolution borehole image. Thereby, allowing derivation of scalable answer products and workflows. Subsequently, explaining water flood mechanism and enabling updating of simulation model for enhanced reservoir characterization. Furthermore, this also allows for field development augmentation and injection strategy optimization through linking of dynamic results to reservoir description of two major sub-layers of this giant carbonate field.\u0000 Integration and analysis of key insights on vertical communication and carbonate anisotropy with major ge","PeriodicalId":215106,"journal":{"name":"Day 2 Wed, January 25, 2023","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-01-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126842778","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}