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Summary Polymer gel has been used for water conformance control for several decades and may have significant potential in remediating unfavorable carbon dioxide (CO2) flow in the subsurface. High-mobility CO2 may channel quickly through sedimentary reservoirs, where unfavorable displacements are worsened in the presence of heterogeneities. Flow diversion technology targeting and withstanding CO2 is therefore essential to improving sweep efficiency and increasing storage potential. Polymer gel treatments have been demonstrated to remediate CO2 channeling in several enhanced oil recovery (EOR) field applications and have been proposed as a means to remediate wellbore and seal leakage during carbon sequestration. The goal of this review is to assess CO2 conformance control by polymer gel in published laboratory work related to both storage and EOR operations. Although field implementation of polymer gel has been successful in reducing CO2 flow, supporting experimental work on the laboratory scale is scattered, with both results and parameters varied. This paper summarizes the available literature and proposes a framework for future experimental work to aid more systematic assessment.
- North America > United States > Texas (1.00)
- Europe (1.00)
- North America > Canada (0.93)
- Asia (0.68)
- Research Report > Experimental Study (0.67)
- Overview (0.66)
- Research Report > New Finding (0.46)
- North America > United States > Wyoming > Wertz Field (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (39 more...)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Oil-Water Flowing Experiments and Water-Cut Range Classification Approach Using Distributed Acoustic Sensing
Liu, Junrong (School of Petroleum Engineering, China University of Petroleum (East China) (Corresponding author)) | Han, Yanhui (Research Institute of Petroleum Engineering Technology, Sinopec Shengli Oilfield Company) | Jia, Qingsheng (Research Institute of Petroleum Engineering Technology, Sinopec Shengli Oilfield Company) | Zhang, Lei (Research Institute of Petroleum Engineering Technology, Sinopec Shengli Oilfield Company) | Liu, Ming (Research Institute of Petroleum Engineering Technology, Sinopec Shengli Oilfield Company) | Li, Zhigang (School of Petroleum Engineering, China University of Petroleum (East China) / National Engineering Research Center of Oil & Gas Drilling and Completion Technology)
Research Institute of Petroleum Engineering Technology, Sinopec Shengli Oilfield Company Summary The accurate measurement of dynamic water cut is of great interest for analyzing reservoir performance and optimizing oilwell production. Downhole water-cut measurement is a very challenging work. Moreover, the surface-measured water cut is a comprehensive indicator of commingled producing well and it is difficult to use this parameter to deduce the downhole water cut of each contributing layer. In this paper, we propose to use distributed fiberoptic acoustic sensing (DAS) technology for the classification of water-cut range. DAS can dynamically monitor the entire wellbore by "listening" to the acoustic signals during flow. A large number of laboratory experimental data from DAS have been collected and analyzed using wavelet time scattering transform and short-time Fourier transform (STFT). The extracted low-variance scattering feature, short time-frequency feature, and fusion feature (combination of two extracted features) were learned with backpropagation (BP) neural network, decision tree (DT), and random forest (RF) algorithm. Then, a classification method of water-cut range in oil-water flow was established with machine learning. Field DAS data were collected from two oil wells to verify the effectiveness of the proposed method. The classification accuracies for the vertical well (Well A) are 92.4% and 87.4% by DT and RF model, respectively. For the horizontal well (Well B), the average classification accuracy exceeds 90% for all three methods. Water shutoff measure was conducted in Well B, and an obvious water decrease was realized. The result shows that the fusion feature overweighs single feature in machine learning with DAS data. This study provides a novel way to identify downhole water-cut range and detect water entry location in horizontal, vertical, and deviated oil-producing wells. Introduction Both temporal and spatial information on water flow rate from an oil well perforated through multilayers is important for predicting oil production rates, tracking reservoir performance, and optimizing oilwell production (Alkhalaf et al. 2019).
- Europe (1.00)
- Asia > China (0.68)
- Asia > Middle East > UAE (0.46)
- North America > United States > Texas (0.28)
- Geology > Rock Type (0.68)
- Geology > Geological Subdiscipline (0.67)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (24 more...)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Development of Novel Delayed Swelling Polymer Gel Particles with Salt Resistance for Enhanced In-Depth Permeability Control
Wu, Yining (College of Petroleum Engineering, China University of Petroleum / Shandong Key Laboratory of Oilfield Chemistry) | Zhang, Haiqing (College of Petroleum Engineering, China University of Petroleum / Shandong Key Laboratory of Oilfield Chemistry) | Zhang, Liyuan (College of Petroleum Engineering, China University of Petroleum / School of Engineering and Applied Sciences, Harvard University (Corresponding author)) | Huang, Yongping (College of Petroleum Engineering, China University of Petroleum / Shandong Key Laboratory of Oilfield Chemistry) | Zhao, Mingwei (College of Petroleum Engineering, China University of Petroleum / Shandong Key Laboratory of Oilfield Chemistry) | Dai, Caili (College of Petroleum Engineering, China University of Petroleum / Shandong Key Laboratory of Oilfield Chemistry (Corresponding author))
School of Engineering and Applied Sciences, Harvard University Summary Prolonged waterflooding or polymer flooding in oil fields often exacerbates reservoir heterogeneity, leading to premature water breakthrough and high water cut, which significantly hinders efficient oilfield development. To address this issue, polymer gel particles have been prescribed to enhance sweep efficiency and augment waterflooding recovery by plugging preferential pathways within the reservoir. However, inherent weaknesses of polymer gel particles, such as fast water absorption and expansion rates in the initial stage and low post-expansion rates, make it difficult to balance in-depth transportation and plugging performance. Additionally, these gel particles are sensitive to ions in the formation water, resulting in reduced expansion rates under high-salinity conditions. Therefore, there are still challenges in the application of polymer gel particles for in-depth permeability control. In this study, a new type of delayed swelling and salt-resistant polymer gel particle was synthesized through inverse emulsion copolymerization. To achieve delayed swelling, we use a degradable crosslinker and hydrophobic monomer to enhance the crosslinked network density and hydrophobicity of gel particles. Coreflooding experiments demonstrate that the residual resistance before and after aging increases from 2.37 to 6.82. The newly synthesized delayed swelling and salt-resistant polymer gel particles exhibit promising potential for overcoming the challenges associated with reservoir heterogeneity and high salinity. Introduction Premature water breakthroughs and high water cuts are common challenges faced in oil fields worldwide (Thomas et al. 2002). These issues arise due to the presence of highly permeable pathways in the formations, significantly reducing the effectiveness of waterflooding or polymer flooding. Consequently, a substantial amount of crude oil remains trapped in inaccessible areas of the reservoir that cannot be displaced (Seright 1997; McGuire et al. 2000; Toole and Grist 2003; Wei 2013; Li et al. 2013; Muggeridge et al. 2014; Zhao et al. 2021).
- South America (1.00)
- Europe (1.00)
- Asia (0.93)
- (2 more...)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Salema Field (0.99)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- North America > United States > Alaska > North Slope Basin > Prudhoe Bay Field (0.99)
- (2 more...)
Feasibility of Foam-Enhanced Water-Gas Flooding for a Low-Permeability High-Fractured Carbonate Reservoir. Screening of Foaming Agent and Flooding Simulation
Derevyanko, V. K. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Bolotov, A. V. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Minkhanov, I. F. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Varfolomeev, M. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Usmanov, S. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Saifullin, E. R. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Egorov, A. N. (CJSC, Aloil, Bavly, Russian Federation) | Sudakov, V. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Zhanbossynova, S (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Sagirov, R. N. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation)
Abstract The carbonate reservoirs of the Alekseevskoye field (Russia, Republic of Tatarstan) are complicated by high heterogeneity and the presence of fractures, which make development difficult due to early water or gas breakthrough depending on the injected agent, as well as low of the productive horizon. To increase sweep efficiency and introduce fractured reservoirs into development, it is necessary to use gas enhanced oil recovery (EOR) technologies. To find the optimal technology in terms of technological complexity and efficiency, three technologies were compared: Water Injection (WI), Water-Alternating Gas (WAG), and Foam Assisted Water-Alternating Gas (FAWAG). Series of core-flooding tests were implemented under reservoir conditions on carbonate cores, and cores with artificial fractures, saturated with original reservoir fluids. For FAWAG method compatible with high-mineralization water surfactant was chosen. Total recovery factor for each test was calculated. It was equal to 33%, 76% and 53% respectively for WI, WAG and SWAG, on the original core models. Therefore, WAG and SWAG were chosen as most effective techniques to improve oil recovery for in comparison with CWI. In artificially fractured cores, the WAG method recovery rate was 40%; subsequent injection of a foaming active substance mixed with FAWAG formation water proved effective, increasing the oil recovery rate to 47% due to partial blockage of the fracture.
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Fractured Carbonate Reservoir Play (0.40)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- Europe > Russia > Volga Federal District > Bashkortostan > Alekseevskoye Field (0.99)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Fyodorovskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Samotlorskoye Field (0.94)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
Real-Time Ultra-Deep Azimuthal Resistivity Inversion Helps to Maximize Asset Value in West Kuwait by Locating Oil-Water Contact Below the Target Well Trajectory
Gezeery, T. (Kuwait Oil Company) | Halawah, Y. (Kuwait Oil Company) | Al Haddad, M. (Kuwait Oil Company) | Al Sabea, S. (Kuwait Oil Company) | Abdulkarim, A. (Halliburton)
Abstract The Burgan sandstone reservoir in the Minagish field of Kuwait is a complex depositional sequence that makes targeting Upper Burgan sands unpredictable due to channeling limiting the reservoir exposure. The area is complicated further by oil-water contact (OWC) uncertainty due to the long history of oil production. The objective of the well was real-time OWC mapping to provide reservoir insight, maximize pay zone exposure and extend the well life through optimizing the completion and production regime. Recent production pulsed-neutron capture (PNC) logging in an offset well showed watering in the Upper Burgan reservoir. This might indicate a change in the level of the OWC or water coning. Utilization of an ultra-deep azimuthal resistivity (UDAR) mapping service was planned to help locate the OWC below the well trajectory and simultaneously identify and track the desired target sandstone sequence. UDAR has proven its capability to map reservoir boundaries and the OWC in real time, during drilling, earlier than with traditional methods. This facilitates real-time geosteering to drill the well in a single run in the productive zone. The wellbore was placed in the desired zone by using UDAR real-time 1D inversion services. While drilling it had been discovered that the OWC was deeper than expected. The reservoir management team obtained important information to update the oilfield development. UDAR services helped to increase reservoir exposure of the well in the Burgan sand of the Minagish oilfield and enhanced the understanding of the sand deposition structure. It was evident that PNC results in the producing offset well do not represent the OWC level throughout the field; instead, localized measurements may be affected by water coning in that specific area. This information led to a change in the field development strategy. The UDAR real-time 1D inversion enabled optimization of the completion design and perforation intervals, and the understanding of the reservoir potential has been improved. The accurate OWC level evaluation will allow to place more production wells in this location.
- Geology > Sedimentary Geology (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Mineral (0.95)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.90)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (0.68)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- (24 more...)
Smart Well Completions: A Comprehensive Review of Technologies, Applications and Challenges
Khan, Mudassir (Mari Petroleum Company Limited, Islamabad, Pakistan) | Inam, Sahir (Mari Petroleum Company Limited, Islamabad, Pakistan) | Hussnain, Sana ul (Mari Petroleum Company Limited, Islamabad, Pakistan) | Aijaz, Muhammad Jahanzaib (Mari Petroleum Company Limited, Islamabad, Pakistan) | Ullah, Rafi (Mari Petroleum Company Limited, Islamabad, Pakistan) | Shafee, Imran (Mari Petroleum Company Limited, Islamabad, Pakistan) | Haider, Mateen (Mari Petroleum Company Limited, Islamabad, Pakistan) | Ahmad, Haiwad (Mari Petroleum Company Limited, Islamabad, Pakistan) | Qureshi, Haris Ahmed (Mari Petroleum Company Limited, Islamabad, Pakistan) | Bashir, Ibtihaj Atiq (Mari Petroleum Company Limited, Islamabad, Pakistan)
Abstract The objective of this paper is to provide a comprehensive review of smart well completion technologies. These technologies are being effectively utilized around the globe for production enhancement, effective reservoir monitoring and management, and reservoir performance, which has always been the main focus of oil and gas industry. Efficacy for the applications of such technologies in specific cases is discussed and the associated challenges are analyzed. Extensive literature review of the past and contemporary technologies has been conducted to understand the evolution of smart completions. Thorough review has been conducted to grasp the specific applications and challenges associated with it. As the application of technology is widespread, specific cases pertaining to multilayered and compartmentalized reservoirs were selected where the solutions were deployed for better control and reservoir management. The operational complexity in these completions related to deployment and future well interventions is also covered. Further, review of smart completion system, its components and implementation, challenges faced during the designing and execution and different applications to address major problems such as, auto gas lift, production optimization production of thin and high water cut reservoirs, effective reservoir management and remote operations is also taken into account. As the industry embraces digitalization and automation, smart well completion is poised to play a pivotal role in shaping the future of oil and gas operations. Successful application of smart or intelligent completions globally have enabled operators to manage complex subsurface reservoirs effectively. Moreover, a combination of such technologies has proved to be vital in multilateral wells enabling downhole monitoring and control. The solutions provide downhole monitoring, enabling real time analysis and on spot decision making. Based on different solutions and technologies available, an analogy has been derived to deploy a tailored solution for multilayered reservoir. Selection of equipment based on different requirements and applications has been presented to derive cost benefit as well as to keep challenges at bay by reducing interventions. Also, the specific application of fiber optics for real-time monitoring of acoustic and temperature measurements is compared as a substitute of production logging tools can prove beneficial and provide monitoring requirements over the life of the well.
Investigation of Carbonate Matrix Damage and Remediation Methods for Preformed Particle Gel Conformance Control Treatments
Almakimi, Abdulaziz A. (Kuwait Institute for Scientific Research) | Liu, Junchen (Missouri University of Science and Technology) | Bai, Baojun (Missouri University of Science and Technology) | Hussein, Ibnelwaleed A. (Missouri University of Science and Technology (Corresponding author))
Summary Preformed particle gels (PPGs) have been widely applied to control excessive water production in mature oil fields with fractures or fracture-like features, especially in sandstones, but with limited attention to carbonates. However, a vital concern arises regarding the potential damage of PPGs on the adjacent matrix that might promote negative results. This paper comprehensively evaluates PPGs’ potential damage to the carbonate matrix and seeks design optimization solutions. Filtration tests were applied to compare PPGs’ penetration into the matrix under different sets of conditions. The filtration regimes were defined by filtration curves, and the gel damage on the matrix was determined by permeability measurement results. Experiments were conducted to investigate the efficiency of an oxidizer as a remediation method to remove the damage. The qualitative description of gel particles’ invasion and plugging behavior in the carbonate matrix was presented based on the analysis of filtration test results and permeability measurements. The results show that the swollen gel filtration curves can be divided into three regions: prior-filter-cake, filter-cake-building, and stable stages according to the gel particles’ response to the injection pressure and effluent flow rates. PPGs can form cakes on the rock surface to prevent particles’ further penetration into the carbonate matrix, and the penetration was only limited to less than a few millimeters. The smallest gel particles (50–70 US mesh size) were more likely to form external and internal filter cakes at higher pressure values (700 psi) and result in more damage to the matrix. To restore the matrix permeability after filtration tests, oxidizer soaking proved to be a reliable solution. In all, the results indicated that unintentional matrix permeability damage induced by gel injection is generally unavoidable but conditionally treatable.
- Asia > Middle East (0.68)
- North America > United States > Oklahoma (0.28)
- North America > United States > Texas (0.28)
- Research Report > New Finding (0.88)
- Research Report > Experimental Study (0.66)
Integrated Workflow for Reservoir Management in Mature Waterflooded Reservoir within a Complex Geological Environment: Gullfaks Case Study
Kareb, Ahmed (University of Houston, Houston) | Dindoruk, Birol (University of Houston, Houston) | Chiboub-Fellah, Abd Elaziz (IFP School, Paris) | Gareche, Mourad (University of Boumerdes, Boumerdes)
In the context of field development planning, the project workflow has to be outlined beforehand to ensure the most optimal and accurate outcomes within time limits. The workflow started by utilizing a G&G software, Petrel, to depict the rock type and fault distribution within the geological models by incorporating interpreted seismic data and well logs. This integrated approach facilitated a comprehensive understanding of the reservoir's structural and geological characteristics. Furthermore, standard geostatistical techniques applied in software generated property models that ensured alignment of permeability and porosity distribution with the corresponding well logs. Interpretation of production data, PVT, and SCAL served as the basis for initializing the model using a reservoir simulator, Intersect, as a dynamic flow simulator. The accuracy and reliability of the model were ensured through quality checks, which include volume estimate comparison starting with equilibrium runs. Additionally, sensitivity analysis was performed by adjusting model parameters to achieve a history match and align simulated results with actual reservoir behavior in various ways. The calibrated model explored using a high-resolution simulator for high accuracy and more options for development strategies such as infill wells (horizontal and vertical), well conversions, water shut-off (zonal isolation and selective perforation), stimulation operations, and ESP systems in order to optimize reservoir performance and maximize production while improving sweep efficiency. Lastly, economic evaluation based on net present value (NPV) analysis considered techno-economic factors to identify the most suitable development strategy that balanced technical feasibility with economic viability.
- North America > United States (0.94)
- Europe > Norway > North Sea > Northern North Sea (0.70)
- Geology > Rock Type (0.88)
- Geology > Geological Subdiscipline (0.68)
- Geology > Structural Geology > Fault (0.47)
- Geophysics > Borehole Geophysics (0.88)
- Geophysics > Seismic Surveying (0.54)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > Statfjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Statfjord Group (0.99)
- (7 more...)
- Information Technology > Software (0.50)
- Information Technology > Modeling & Simulation (0.47)
- Information Technology > Software Engineering (0.41)
Dynamic Wettability Alteration at Pore-Scale Using Viscoelastic Surfactant/Chelating Agents Systems
Ahmed, M. Elmuzafar (Petroleum Engineering Department, College of Petroleum Engineering & Geosciences, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Sultan, Abdullah S. (Petroleum Engineering Department, College of Petroleum Engineering & Geosciences, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia)
Abstract The role of wettability is crucial in the extraction of hydrocarbons as it determines how well the oil adheres to the rock surface, directly impacting the efficiency of the extraction process. Numerous studies have been conducted to modify the wettability of rocks to a favorable state. In this study, we delve into the microscopic level to observe the actual process of altering the contact angle during flooding using microfluidic technology within a glass micromodel. Initially, the micromodel is saturated with formation water and subsequently displaced by oil to establish the initial oil saturation. The microfluidic setup consists of a precise pump for flood control and a high-speed microscope to capture images for later analysis using image processing software to obtain the actual contact angle. The contact angle is measured at five arbitrary locations, and the average is calculated at specific time intervals based on image analysis. Three different fluid systems were utilized: pure Viscoelastic Surfactant (VES), VES with DTPA, and VES with GLDA. The concentration of these systems was selected based on optimal rheology and interfacial tension performance. The contact angle was measured at various injection stages to observe its dynamic change from the initial state to the final state and assess the resulting recovery from each fluid system. The pure VES system modified the wettability from slightly oil-wet to slightly water-wet and achieved a 48% recovery of the original oil in place (OOIP). On the other hand, the addition of DTPA altered the wettability from slightly oil-wet to extremely water-wet; however, this did not lead to higher recovery, and water breakthrough occurred, reducing the sweep efficiency with a 45% recovery. The GLDA VES system altered the wettability to moderately water-wet, which proved to be the most favorable wettability condition, resulting in a 56% ultimate recovery. This investigation successfully demonstrated the effectiveness of using VES-assisted chelating agents in altering rock wettability and increasing oil recovery at the pore scale.
- Africa (0.68)
- South America > Brazil (0.46)
- Asia > Middle East (0.28)