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1
Chen, Bailian, and Albert C. Reynolds. "Ensemble-Based Optimization of the Water-Alternating-Gas-Injection Process." SPE Journal 21, no. 03 (2016): 0786–98. http://dx.doi.org/10.2118/173217-pa.
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Summary CO2-water-alternating-gas (CO2-WAG) flooding generally leads to higher recovery than either continuous CO2 flooding or waterflooding. Although CO2 injection increases microscopic displacement efficiency, unless complete miscibility is achieved, suboptimal sweep efficiency may be obtained because of gravity segregation and the channeling of CO2 through high-permeability zones or by viscous fingering. Alternating water injection with CO2 injection results in better mobility control and increases sweep efficiency. Water injection also increases pressure that promotes miscibility. However, poorly designed WAG parameters can result in suboptimal WAG performance. In this work, given the number of WAG cycles and the duration of each WAG cycle, we apply a modification of a standard ensemble-based optimization technique to estimate the optimal well controls that maximize life-cycle net present value (NPV). By optimizing the well controls, we implicitly optimize the WAG ratio (volume of water injected divided by the volume of gas injected). We apply the optimization methodology to a synthetic, channelized reservoir. The performances of optimized WAG flooding, optimized waterflooding, and optimized continuous CO2 flooding are compared. Because of the similarity between WAG and surfactant alternating gas (SAG foam), we also optimize the SAG process and provide a more computationally efficient way to optimize the SAG process with the optimal well controls obtained from WAG as the initial guesses for the optimal controls for SAG.
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Lu, Cong, Li Ma, Jianchun Guo, et al. "Fracture Parameters Optimization and Field Application in Low-Permeability Sandstone Reservoirs under Fracturing Flooding Conditions." Processes 11, no. 1 (2023): 285. http://dx.doi.org/10.3390/pr11010285.
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To solve engineering problems in the production process after fracturing and flooding of low-permeability sandstone reservoirs, such as rapid water-cut rise and low water flooding efficiency, a method for optimizing the fracture parameters of low-permeability sandstone reservoirs under fracturing flooding conditions was proposed. A rock property test experiment was first carried out, the fracturing coefficient was defined, and an evaluation method for the brittleness index of low-permeability sandstone was established to optimize the perforation location of the fracturing reservoir. A productivity numerical model for the two-phase flow of oil–water in matrix–fracture media was established to optimize the fracture morphology under fracturing flooding conditions. The results showed that the quartz content, Young’s modulus, and peak stress mainly affected the fracturing coefficient of rock and are the key indicators for evaluating the brittleness of low-permeability sandstone reservoirs. For production wells in the direction of minimum horizontal principal stress, the swept area of water flooding should be expanded, fracture length should be optimized to 90 m, and fracture conductivity should be 20 D·cm. For fracturing production wells in the direction of maximum horizontal principal stress, the advancing speed of the water injection front should be slowed down to reduce the risk of water channeling in injection-production wells. The optimized fracture length was 80 m, and the fracture conductivity was 25 D·cm. The application of these findings can markedly improve oil production and provide a reference for optimizing the fracture parameters of low-permeability sandstone reservoirs under fracturing flooding conditions.
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Nguyen, Dang-Quan, and Pascale Minet. "Quality of Service Routing in a MANET with OLSR." JUCS - Journal of Universal Computer Science 13, no. (1) (2007): 56–86. https://doi.org/10.3217/jucs-013-01-0056.
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Ad hoc wireless networks have enormous commercial and military potential becauseof their self-organizing capacity and mobility support. However, some specificities of these networks such as radio interferences and limited resources make more complex the quality of service(QoS) support. Indeed, on the one hand, the bandwidth offered to users is strongly affected by radio interferences. On the other hand, flooding information in such a network must be optimizedin order to save resources. Therefore, we propose in this paper, a solution taking into account radio interferences in mobile ad hoc network routing and optimizing flooding. This solution isbased on a modified version of the OLSR routing protocol that considers bandwidth requests and radio interferences in the route selection process while providing a very efficient flooding.A comparative performance evaluation based on NS simulations shows that despite the overhead due to QoS management, this solution outperforms classical OLSR in terms of QoS perceivedby the users (e.g. bandwidth amount granted to a flow and delivery rate). The efficiency of the optimized flooding is equal to that provided by the native version of OLSR.
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Wu, Yuanbo, and Qihong Feng. "Integrated Geology-Engineering Approach for Fracturing-Flooding Parameter Optimization in Low-Permeability Reservoirs." Advances in Engineering Technology Research 12, no. 1 (2025): 1437. https://doi.org/10.56028/aetr.12.1.1437.2024.
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The development of low-permeability reservoirs faces challenges such as low water injection efficiency and poor pressure transmission. Fracturing-Flooding technology enhances reservoir seepage capacity and effectively replenishes formation energy through high-pressure, large-volume fluid injection. This study employs an integrated geological and engineering approach, combining geological modeling, fracture propagation simulation, and reservoir numerical simulation to optimize Fracturing-Flooding parameters. Results demonstrate the following optimized parameters for the Y well group: Fracturing-Flooding water injection volume of 3.5×10⁴ m³, injection rate of 1.3–1.6 m³/min, post-fracturing shut-in period of 30–40 days, production pressure difference of 8–12 MPa, and injection-production ratio of 0.9–1.1.
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Gomez, Javier, Martha Montes-de-Oca, and Jose Jaime Camacho-Escoto. "Flood and Contain: An Optimized Repeal-Based Flooding Algorithm for Wireless Ad Hoc and Sensor Networks." Sensors 20, no. 20 (2020): 5914. http://dx.doi.org/10.3390/s20205914.
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Flooding is a simple yet reliable way of discovering resources in wireless ad hoc networks such as mobile ad hoc networks (MANETs), ad hoc sensors, and recently, IoT networks. However, its operation is resource-intensive, especially in densely populated networks. Several approaches can be found in the literature to reduce the impact of flooding. Many of these approaches follow a repeal-based operation, chasing and stopping further propagation of flooding packets once the target is found. However, repeal-based protocols might end up transmitting even more packets than the original flooding. This work characterizes a maximum repeal-flooding boundary beyond which it is counterproductive to chase the original flooding. We present the Flood and Contain (F&C) algorithm, a method that can quickly establish the maximum repeal-flooding boundary for each node while making no assumptions on the underlying network. F&C’s packet overhead increases linearly with the hop count up to the maximum repeal-flooding boundary, in which case there is no attempt to chase the original flooding. In this latter case, F&C generates only as many packets as the original flooding. Simulations show that, on average, F&C reduces the total flooding overhead (compared to traditional flooding) up to 35 percent once considering all possible destinations, with only a slight increase in resource discovery latency, and it outperforms all other repeal-based protocols, particularly for longer routes.
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Lu, Jun, and Gary A. Pope. "Optimization of Gravity-Stable Surfactant Flooding." SPE Journal 22, no. 02 (2016): 480–93. http://dx.doi.org/10.2118/174033-pa.
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Summary Horizontal surfactant floods are inherently unstable without mobility control. However, a vertical surfactant flood can be stabilized by gravity if the velocity is below the critical velocity. A modified stability theory was validated by comparison with a series of surfactant-displacement experiments. These experiments also demonstrate that the critical velocity can be increased by optimizing the viscosity of the microemulsion that forms when the surfactant solution mixes with the oil in the porous medium. The microemulsion viscosity is sensitive to formulation variables such as the amount and type of co-solvent added to the surfactant solution. By changing surfactant components, co-solvents, and the concentration of the co-solvents, we were able to successfully control the microemulsion viscosity at optimum salinity to optimize the critical velocities in each surfactant flood. The experiments with optimized microemulsions show that the surfactant-flood velocity can be significantly increased and still recover nearly 100% of the oil.
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Sun, Chen, Jian Hou, Guangming Pan, and Zhizeng Xia. "Optimized polymer enhanced foam flooding for ordinary heavy oil reservoir after cross-linked polymer flooding." Journal of Petroleum Exploration and Production Technology 6, no. 4 (2016): 777–85. http://dx.doi.org/10.1007/s13202-015-0226-2.
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Flores-Marquez, Ricardo, Rita de Cássia Bahia, Yuri Arévalo-Aranda, et al. "Intermittent Rainfed Rice var. INIA 516 LM1: A Sustainable Alternative for the Huallaga River Basin." Water 17, no. 9 (2025): 1262. https://doi.org/10.3390/w17091262.
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Climate change is projected to increase global temperatures and alter rainfall patterns. In Peru, these changes could adversely affect the central basin of the Huallaga River by increasing pest and disease incidence, evapotranspiration, and water consumption. This basin is one of the country’s main rice-producing regions, where the crop is traditionally cultivated using inefficient practices, such as continuous flood irrigation. This study evaluated the effects of different irrigation management strategies on the growth and yield of rice (Oryza sativa var. INIA 516 LM1-La Unión 23), the water footprint as an indicator of water use efficiency, and the incidence of pests and diseases associated with irrigation regimes. Three irrigation treatments were implemented: Traditional flooding T1 (maintenance of a 0.15 m water layer with replenishment every 4 days), Optimized flooding T2 (replenishment every 7 days), and Intermittent rainfed irrigation T3 (replenishment every 14 days). Although no significant differences were observed in biometric parameters, yield, or pest and disease incidence, a trend of decreasing yield with longer irrigation intervals was noted: traditional flooding (7.91 t∙ha−1) > reduced flooding (7.82 t∙ha−1) > intermittent rainfed (7.14 t∙ha−1). The incidence of white leaf virus and Burkholderia glumae was highest in the intermittent rainfed treatment, followed by optimized flooding, with the lowest incidence in traditional flooding. Yield reduction and the use of rainwater to cover water requirements resulted in a lower total water footprint for traditional flooding (834.0 m3∙t−1), followed by optimized flooding (843.6 m3∙t−1) and intermittent rainfed (923.9 m3∙t−1). This reflects an improvement in rainwater use efficiency. The findings suggest intermittent rainfed irrigation enhances water use efficiency without significantly compromising rice yield or increasing disease incidence in rice var. INIA 516 LM1-La Unión 23 in the central basin of the Huallaga River.
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LIPMAN, JUSTIN, PAUL BOUSTEAD, and JOHN JUDGE. "NEIGHBOR AWARE ADAPTIVE POWER FLOODING (NAAP) IN MOBILE AD HOC NETWORKS." International Journal of Foundations of Computer Science 14, no. 02 (2003): 237–52. http://dx.doi.org/10.1142/s0129054103001704.
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This paper introduces Neighbor Aware Adaptive Power flooding, an optimized flooding mechanism used in mobile ad hoc networks (MANETS) that employs several mechanisms (neighbor coverage, power control, neighbor awareness and local optimization) to limit the broadcast storm problem, reduce duplicate packet reception and lower power consumption in both transmission and reception. Upon receiving an optimized broadcast, a relay determines a new set of possible relays (to continue the flood) based upon local neighbor information and the previous optimized broadcast. Additionally, neighboring relays only consider the shared neighbors they are closest to. A relay may perform local optimization (to reduce power consumption and isolate broadcasts) by substituting one high power broadcast with two or more low power broadcasts, thereby introducing additional hops, We show that compared to blind flooding and multipoint relaying, NAAP in a static environment greatly reduces the problems associated with the broadcast storm problem, duplicate packet reception and power consumption.
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Guo, Junhui, Erlong Yang, Yu Zhao, et al. "A New Method for Optimizing Water-Flooding Strategies in Multi-Layer Sandstone Reservoirs." Energies 17, no. 8 (2024): 1828. http://dx.doi.org/10.3390/en17081828.
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As one of the most important and economically enhanced oil-recovery technologies, water flooding has been applied in various oilfields worldwide for nearly a century. Stratified water injection is the key to improving water-flooding performance. In water flooding, the water-injection rate is normally optimized based on the reservoir permeability and thickness. However, this strategy is not applicable after oilfields enter the ultra-high-water-cut period. In this study, an original method for optimizing water-flooding parameters for developing multi-layer sandstone reservoirs in the entire flooding process and in a given period is proposed based on reservoir engineering theory and optimization technology. Meanwhile, optimization mathematical models that yield maximum oil recovery or net present value (NPV) are developed. The new method is verified by water-flooding experiments using Berea cores. The results show that using the method developed in this study can increase the total oil recovery by approximately 3 percent compared with the traditional method using the same water-injection amounts. The experimental results are consistent with the results from theoretical analysis. Moreover, this study shows that the geological reserves of each layer and the relative permeability curves have the greatest influence on the optimized water-injection rate, rather than the reservoir properties, which are the primary consideration in a traditional optimization method. The method developed in this study could not only be implemented in a newly developed oilfield but also could be used in a mature oilfield that has been developed for years. However, this study also shows that using the optimized water injection at an earlier stage will provide better EOR performance.
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Song, Dong-Soo, and Sang-Yeol Kim. "Optimized Flooding Analysis Method for Compartment for Nuclear Power Plant." Journal of Energy Engineering 21, no. 1 (2012): 75–80. http://dx.doi.org/10.5855/energy.2012.21.1.075.
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Jalili, Hamidreza, Lizette Chevalier, and John W. Nicklow. "Optimization of Real-Time Control Approach: Number, Placement, and Proportional–Integral–Derivative Control Rules of Flow Control Devices in Distributed Flood Routing." Water 16, no. 22 (2024): 3331. http://dx.doi.org/10.3390/w16223331.
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Climate change, through more frequent extreme weather events, and urban sprawl, by increasing runoff, are two critical threats to drainage networks, impacting both public health and property. Augmenting drainage networks to withstand additional stress by enlarging conduits or constructing new detention facilities requires a significant financial investment. The goal of this study is to enhance urban resilience by optimizing real-time control (RTC) systems for drainage networks that optimize the flow control devices (FCDs), which could mitigate the need to invest in major construction costs. RTC is an approach that can help mitigate flooding in urban areas. This study is the first to optimize feedback controllers in SWMM, as well as the first to simultaneously optimize the number, location, and proportional–integral–derivative (PID) controllers for FCDs through two nested genetic algorithms (GAs), and especially within a unified environment (i.e., Python), which led to more efficient management of the process, thereby enhancing the efficiency of urban drainage network optimization. This study examined the impact of optimized RTC on the urban drainage network (UDN) in a part of New Orleans, LA, USA, under 1-, 2-, 5-, and 10-year storm events. The optimized RTC resulted in an improvement of up to 50% in network performance during a design storm. The results demonstrate the applicability in an urban environment where storms, flooding, and financial investments are critical to the management of stormwater drainage.
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Ghori, Muhammad Rizwan, Tat-Chee Wan, Gian Chand Sodhy, and Amna Rizwan. "Optimization of the AODV-Based Packet Forwarding Mechanism for BLE Mesh Networks." Electronics 10, no. 18 (2021): 2274. http://dx.doi.org/10.3390/electronics10182274.
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The standard Bluetooth Low-Energy mesh networks assume the use of flooding for multihop communications. The flooding approach causes network overheads and delays due to continuous message broadcasting in the absence of a routing mechanism. Among the routing protocols, AODV is one of the most popular and robust routing protocol for wireless ad hoc networks. In this paper, we optimized the AODV protocol for Bluetooth Low-Energy communication to make it more efficient in comparison to the mesh protocol. With the proposed protocol (Optimized AODV (O-AODV)), we were able to achieve lower overheads, end-to-end delay, and average per-hop one-way delay in comparison to the BLE mesh (flooding) protocol and AODV protocol for all three scenarios (linear topology with ten nodes, multipath topology with six and ten nodes). In addition, the proposed protocol exhibited practically constant route requests and route reply setup times. Furthermore, the proposed protocol demonstrated a better Packet Delivery Ratio (PDR) for O-AODV (84%) in comparison to AODV (71%), but lower than the PDR of the mesh (flooding) protocol with 93%.
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Yue, Ming, Quanqi Dai, Haiying Liao, Yunfeng Liu, Lin Fan, and Tianru Song. "Prediction of ORF for Optimized CO2 Flooding in Fractured Tight Oil Reservoirs via Machine Learning." Energies 17, no. 6 (2024): 1303. http://dx.doi.org/10.3390/en17061303.
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Tight reservoirs characterized by complex physical properties pose significant challenges for extraction. CO2 flooding, as an EOR technique, offers both economic and environmental advantages. Accurate prediction of recovery rate plays a crucial role in the development of tight oil and gas reservoirs. But the recovery rate is influenced by a complex array of factors. Traditional methods are time-consuming and costly and cannot predict the recovery rate quickly and accurately, necessitating advanced multi-factor analysis-based prediction models. This study uses machine learning models to rapidly predict the recovery of CO2 flooding for tight oil reservoir development, establishes a numerical model for CO2 flooding for low-permeability tight reservoir development based on actual blocks, studies the effects of reservoir parameters, horizontal well parameters, and injection-production parameters on CO2 flooding recovery rate, and constructs a prediction model based on machine learning for the recovery. Using simulated datasets, three models, random forest (RF), extreme gradient boosting (XGBoost), and light gradient boosting machine (LightGBM), were trained and tested for accuracy evaluation. Different levels of noise were added to the dataset and denoised, and the effects of data noise and denoising techniques on oil recovery factor prediction were studied. The results showed that the LightGBM model was superior to other models, with R2 values of 0.995, 0.961, 0.921, and 0.877 for predicting EOR for the original dataset, 5% noise dataset, 10% noise dataset, and 15% noise dataset, respectively. Finally, based on the optimized model, the key control factors for CO2 flooding for tight oil reservoirs to enhance oil recovery were analyzed. The novelty of this study is the development of a machine-learning-based method that can provide accurate and cost-effective ORF predictions for CO2 flooding for tight oil reservoir development, optimize the development process in a timely manner, significantly reduce the required costs, and make it a more feasible carbon utilization and EOR strategy.
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Cheng, Keyang, Zhaoting Huang, Jun Li, Taotao Luo, and Hongbo Li. "Experimental Study on Enhancing Heavy Oil Recovery by Multimedia-Assisted Steam Flooding Process." Geofluids 2022 (March 31, 2022): 1–8. http://dx.doi.org/10.1155/2022/1968032.
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Aiming to reduce the negative effect of steam channeling in the late stage of steam flooding applied in heavy oil reservoirs, experimental studies were carried out on selective plugging of solid particles, added to single-medium- and multimedia-assisted steam flooding. This work also explored the mechanisms of enhancing heavy oil recovery by applying plugging agent- and multimedia-assisted steam flooding and its optimized injection parameters. Through solid particle plugging experiments, this study clarifies the high-efficiency solid particle plugging mechanism, with an optimized slug size of 0.40 PV and plugging ratio of over 98%. Through single-medium- and multimedia-assisted steam flooding experiments, this study confirms that gas-assisted steam flooding has an effect of synergistic oil displacement and that a CO2 with urea solution-assisted steam flooding method achieves the best production performance. Its oil recovery factor is 10.7% higher than that of the steam flooding process. Parallel sand pack models with a permeability difference of more than 10 times were used to mimic a heavy oil reservoir with high-permeability channels, and the selective plugging of solid particles was carried out. The plugging ratio of high-permeability formation reached 91.20%, playing an effective plugging role. Solid particle plugging is less effective to the low-permeability formation, with the plugging ratio at only 32.39%. Based on the selective plugging of solid particles, a plugging agent- and multimedia-assisted steam flooding experiment was conducted, the high-permeability formation was effectively plugged, and the swept volume of the low-permeability formation increased significantly. The final recovery factor of the high-permeability formation was enhanced by 11%, and the recovery factor of the low-permeability formation increased by 3 times, reaching 36.38%. Therefore, solid particle plugging effectively alleviates the impact of high-permeability formation caused by permeability difference during steam flooding.
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Shi, Xiaorong, Xiaolin He, Xinqi Zhang, et al. "Experimental Study on Chemical Recovery of Low-Permeability and Medium-Deep Heavy Oil Reservoir." Geofluids 2022 (November 10, 2022): 1–15. http://dx.doi.org/10.1155/2022/9366864.
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To improve the oil recovery of a block in the Wutonggou Formation of the Changji Oilfield, viscosity reducing and foaming agent was optimized to improve the development effect of the water flooding reservoir. The core flooding experiment and microscopic visual experiment were conducted to investigate the production characteristics and EOR mechanism of nitrogen foam flooding. The results show that the 0.5 wt% viscosity reducing and foaming agent DXY-03 was optimized. In the process of microscopic oil displacement by nitrogen foam, nitrogen foam continuously expands and spreads, improves oil displacement efficiency, and greatly improves oil recovery through emulsification and viscosity reduction, squeezing action, dragging action, and Jamin effect. The core flooding experiment shows that on the basis of the water flooding recovery rate of 20.3%, the nitrogen foam huff and puff is increased by 9.2%. The viscosity reducing and foaming agent flooding is increased by 7.8%, and the nitrogen foam flooding is increased by 12.9%. The main EOR mechanism of the viscosity reducing and foaming agent is that it can reduce the interfacial tension between oil and water and can promote heavy oil emulsification and dispersion, thereby forming an oil/water- (O/W-) type emulsion. The reduction in the viscosity of heavy oil makes crude oil easier to extract, realizing the synergistic viscosity reducing and efficiency enhancing effect of nitrogen and viscosity reducing and foaming agents. This study is helpful to provide reference for the development of low-permeability and high-viscosity medium-deep heavy oil reservoirs by chemical agents combined with cold production.
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Zhang, Ruijun, Shuili Yu, Wenxin Shi, et al. "Optimization of a membrane cleaning strategy for advanced treatment of polymer flooding produced water by nanofiltration." RSC Advances 6, no. 34 (2016): 28844–53. http://dx.doi.org/10.1039/c6ra01832g.
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Chen, Xin, Yiqiang Li, Xiaoguang Sun, Zheyu Liu, Jianbin Liu, and Shun Liu. "Investigation of Polymer-Assisted CO2 Flooding to Enhance Oil Recovery in Low-Permeability Reservoirs." Polymers 15, no. 19 (2023): 3886. http://dx.doi.org/10.3390/polym15193886.
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CO2 flooding is a favorable technical means for the efficient development of low-permeability reservoirs, and it can also contribute to the realization of net-zero CO2 emissions. However, due to the unfavorable viscosity ratio and gravity overriding effect, CO2 channeling will inevitably occur, seriously affecting its storage and displacement effects. This paper conducts a systematic study on the application of polymer-assisted CO2 flooding in low-permeability reservoirs. Firstly, the polymer agent suitable for low-permeability reservoirs is optimized through the viscosity-increasing, rheological, and temperature- and salt-resistant properties of the solution. Then, the injectivity performance, resistance-increasing ability, and profile-improving effect of the polymer solution were evaluated through core experiments, and the optimum concentration was optimized. Finally, the enhanced oil recovery (EOR) effects of polymer-assisted and water-assisted CO2 flooding were compared. The results show that the temperature-resistant polymer surfactant (TRPS) has a certain viscosity-increasing performance, good temperature resistance performance, and can react with CO2 to increase the solution viscosity significantly. Meanwhile, TRPS has good injection performance and resistance-increasing effect. The resistance increasing factor (η and η′) of TRPS-assisted CO2 flooding increases with increased permeability, the concentration of TRPS solution, and injection rounds. Considering η′ and the profile improvement effect comprehensively, the application concentration of TRPS should be 1000 mg/L. The EOR effect of TRPS-assisted CO2 flooding is 8.21% higher than that of water-assisted CO2 flooding. The main effective period is in the first and second rounds, and the best injection round is three. The research content of this paper can provide data support for the field application of polymer-assisted CO2 flooding in low-permeability reservoirs.
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Ghori, Muhammad Rizwan, Tat-Chee Wan, Gian Chand Sodhy, et al. "Enhancing Reliability and Stability of BLE Mesh Networks: A Multipath Optimized AODV Approach." Sensors 24, no. 18 (2024): 5901. http://dx.doi.org/10.3390/s24185901.
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Bluetooth Low Energy (BLE) mesh networks provide flexible and reliable communication among low-power sensor-enabled Internet of Things (IoT) devices, enabling them to communicate in a flexible and robust manner. Nonetheless, the majority of existing BLE-based mesh protocols operate as flooding-based piconet or scatternet overlays on top of existing Bluetooth star topologies. In contrast, the Ad hoc On-Demand Distance Vector (AODV) protocol used primarily in wireless ad hoc networks (WAHNs) is forwarding-based and therefore more efficient, with lower overheads. However, the packet delivery ratio (PDR) and link recovery time for AODV performs worse compared to flooding-based BLE protocols when encountering link disruptions. We propose the Multipath Optimized AODV (M-O-AODV) protocol to address these issues, with improved PDR and link robustness compared with other forwarding-based protocols. In addition, M-O-AODV achieved a PDR of 88%, comparable to the PDR of 92% for flooding-based BLE, unlike protocols such as Reverse-AODV (R-AODV). Also, M-O-AODV was able to perform link recovery within 3700 ms in the case of node failures, compared with other forwarding-based protocols that require 4800 ms to 6000 ms. Consequently, M-O-AODV-based BLE mesh networks are more efficient for wireless sensor-enabled IoT environments.
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Ma, Qingsong, Zhanpeng Zheng, Jiarui Fan, et al. "Pore-Scale Simulations of CO2/Oil Flow Behavior in Heterogeneous Porous Media under Various Conditions." Energies 14, no. 3 (2021): 533. http://dx.doi.org/10.3390/en14030533.
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Miscible and near-miscible flooding are used to improve the performance of carbon-dioxide-enhanced oil recovery in heterogeneous porous media. However, knowledge of the effects of heterogeneous pore structure on CO2/oil flow behavior under these two flooding conditions is insufficient. In this study, we construct pore-scale CO2/oil flooding models for various flooding methods and comparatively analyze CO2/oil flow behavior and oil recovery efficiency in heterogeneous porous media. The simulation results indicate that compared to immiscible flooding, near-miscible flooding can increase the CO2 sweep area to some extent, but it is still inefficient to displace oil in small pore throats. For miscible flooding, although CO2 still preferentially displaces oil through big throats, it may subsequently invade small pore throats. In order to substantially increase oil recovery efficiency, miscible flooding is the priority choice; however, the increase of CO2 diffusivity has little effect on oil recovery enhancement. For immiscible and near-miscible flooding, CO2 injection velocity needs to be optimized. High CO2 injection velocity can speed up the oil recovery process while maintaining equivalent oil recovery efficiency for immiscible flooding, and low CO2 injection velocity may be beneficial to further enhancing oil recovery efficiency under near-miscible conditions.
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Andi Radi, Andi Mohd Syaiful, Mazlin Idress, and Farah Rosmaniza Redzuan. "THE STUDY OF THE EFFECT OF TEMPERATURE AND PH VALUE ON ADSORPTION CHARACTERISTICS OF UREA BASED SACRIFICIAL AGENT IN CLAY MINERALS." Platform : A Journal of Engineering 6, no. 4 (2022): 22. http://dx.doi.org/10.61762/pajevol6iss4art20973.
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The Enhanced Oil Recovery (EOR) process has grown within the time oil exploration was conducted, and many recovery methods were invented to maximize production. One of the promising recovery techniques is carbon dioxide (CO2) flooding. However, CO2 flooding has its disadvantages where due to different mobility and heterogeneity between CO2 and reservoir, the sweep efficiency is reduced because of gas channelling and viscous fingering. Thus, the application of surfactant is introduced to solve the problem. But, by using surfactants in CO2 flooding, loss of surfactant to the formation is observed. Due to this setback, the cost of the EOR process increased significantly as more surfactants must be injected due to the loss. To reduce surfactant loss, sacrificial agents are introduced within the application of surfactant in CO2 flooding. The sacrificial agent would be adsorbed onto the clay minerals instead of surfactants. However, the application of sacrificial agent needs to be optimized to ensure a more cost-effective process. Therefore, this study, the adsorption rate of urea-based sacrificial agent in montmorillonite and kaolinite was tested under different pH values and temperatures using a UV-Vis spectrometer. Through the adsorption test, it is observed that the adsorption rate of urea is higher in montmorillonite than in kaolinite. The adsorption rate of urea in montmorillonite and kaolinite are optimized in high-temperature alkaline environment with 1.50 mg/g and 1.46 mg/g of urea adsorbed, respectively.Keywords: CO2 flooding, montmorillonite, kaolinite, sacrificial agent, urea, adsorption rate
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Wang, Jin Feng, Li Jie Feng, and Zhao Hui Li. "The Coal Mine Flooding Emergency Ability Evaluation Based on GA-WNN." Advanced Materials Research 452-453 (January 2012): 782–88. http://dx.doi.org/10.4028/www.scientific.net/amr.452-453.782.
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For the coal resources working which are affected by the coal mine flooding seriously, this paper make an analysis on the factors which affect the coal mine flooding emergency ability evaluation model based on GA-WNN is established through the wavelet neural network value which is optimized with genetic algorithm. This model combined the global optimization ability of genetic algorithm with the time-frequency localization of wavelet neural network. This combination can make up for many defects (for example, the neural network structure should be given artificially, the function can got local minimum easily and so on). Therefore, the local mine flooding emergency ability evaluation model based on genetic algorithm and wavelet neural network have higher reliability and calculation ability, and is beneficial to the pre-control management for coal mine flooding rescue.
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Wu, Han, and Junwu Wang. "A Method for Prediction of Waterlogging Economic Losses in a Subway Station Project." Mathematics 9, no. 12 (2021): 1421. http://dx.doi.org/10.3390/math9121421.
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In order to effectively solve the problems of low prediction accuracy and calculation efficiency of existing methods for estimating economic loss in a subway station engineering project due to rainstorm flooding, a new intelligent prediction model is developed using the sparrow search algorithm (SSA), the least-squares support vector machine (LSSVM) and the mean impact value (MIV) method. First, in this study, 11 input variables are determined from the disaster loss rate and asset value, and a complete method is provided for acquiring and processing data of all variables. Then, the SSA method, with strong optimization ability, fast convergence and few parameters, is used to optimize the kernel function and the penalty factor parameters of the LSSVM. Finally, the MIV is used to identify the important input variables, so as to reduce the predicted input variables and achieve higher calculation accuracy. In addition, 45 station projects in China were selected for empirical analysis. The empirical results revealed that the linear correlation between the 11 input variables and output variables was weak, which demonstrated the necessity of adopting nonlinear analysis methods such as the LSSVM. Compared with other forecasting methods, such as the multiple regression analysis, the backpropagation neural network (BPNN), the BPNN optimized by the particle swarm optimization, the BPNN optimized by the SSA, the LSSVM, the LSSVM optimized by the genetic algorithm, the PSO-LSSVM and the LSSVM optimized by the Grey Wolf Optimizer, the model proposed in this paper had higher accuracy and stability and was effectively used for forecasting economic loss in subway station engineering projects due to rainstorms.
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Jie, Zhang, Cai Ming-Jun, Ge Dangke, et al. "Sensitivity Analysis and Multiobjective Optimization of CO2 Huff-N-Puff Process after Water Flooding in Natural Fractured Tight Oil Reservoirs." Geofluids 2021 (April 20, 2021): 1–9. http://dx.doi.org/10.1155/2021/8890468.
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The CO2 huff-n-puff is an effective substitute technology to further improve oil recovery of natural fractured tight oil reservoirs after water flooding, for its high displacement efficiency and superior injectivity. The CO2 huff-n-puff process is influenced by many factors, such as miscible degree, complex fracture networks, and production schemes. What is worse, those influence facts affect each other making the process more complex. Many researchers concentrated on mechanisms and single sensitivity analysis of CO2 huff-n-puff process, whereas few optimized this process with the consideration of all influence factors and multiobjective to get favorable performance. We built multiobjective consisted of miscible degree, oil recovery, and gas replacing oil rate considering the aspects of CO2 flooding special characteristic, technical effectiveness, and economic feasibility, respectively. We have taken Yuan 284 tight oil block as a case, firstly investigated sensitivity analysis, and then optimized CO2 huff-n-puff process using orthogonal experiment design with multifactors and multiobjectives. The optimization results show CO2 huff-n-puff can significantly improve oil recovery by 8.87% original oil in place (OOIP) compared with water flooding, which offers guidelines for field operations.
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Bengar, Ali, Siyamak Moradi, Mostafa Ganjeh-Ghazvini, and Amin Shokrollahi. "Optimized polymer flooding projects via combination of experimental design and reservoir simulation." Petroleum 3, no. 4 (2017): 461–69. http://dx.doi.org/10.1016/j.petlm.2017.05.006.
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Cao, Lin, Jianlong Xiu, Hongjie Cheng, et al. "A New Methodology for the Multilayer Tight Oil Reservoir Water Injection Efficiency Evaluation and Real-Time Optimization." Geofluids 2020 (November 10, 2020): 1–17. http://dx.doi.org/10.1155/2020/8854545.
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It is important to determine the reasonable injection and production rates in the development of multilayer tight oil reservoir with water flooding treatment. Based on the INSIM (interconnection-based numeric simulation model), a connected network model, a new method is designed to evaluate the water injection efficiency of different layers in water flooding reservoirs and to optimize the injection-production system to produce more oil. Based on the types of sedimentary facies and corresponding injection-production data, the interwell connections are divided into four major categories (middle channel, channel edge, middle channel bar, and channel bar edge) and twelve subclasses. This classification standard of interwell connections could help to significantly improve the accuracy of judging the dominant flow path without constructing a complicated geological model. The interaction of interwells such as injection-production correlation and water injection efficiency could be revealed by simulating the production performance and computing the layer dividing coefficient and well dividing coefficient. A numerical example is used to validate this method by comparing results from FrontSim and this method, and the computational efficiency of this method is several dozen times faster than that of the traditional numerical simulation. This method is applied to quickly optimize the production schedule of a tight oil reservoir with the water flooding treatment, that is, the water injection rate of multilayer reservoirs could be optimized subtly by the injection efficiency of different layers, and the target of producing more oil with lower water cut could be achieved.
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Alaigba, D., O. D. Oduwa, and O. Olafuyi. "Evaluation of selected salts for potential application for optimized salinity water flooding in Niger Delta crude oil-rock systems: A laboratory approach." Nigerian Journal of Technology 40, no. 3 (2021): 404–13. http://dx.doi.org/10.4314/njt.v40i3.7.
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 This work has assessed the comparative performance of four salts (NaCl, K2SO4, CaCl2, and MgSO4) in the optimized salinity water flooding mode. This was done by carrying out core flooding tests using crude oil, brines and cores sourced from a Niger Delta field. Inter-facial Tension tests were also performed on each crude brine system to understand the specific role of fluid-fluid interaction. The results obtained from the study are quite interesting as additional recovery ranging from 5–26% were obtained in the secondary and tertiary mode.
 
 
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Gao, Xiding, Liehui Zhang, Lei Qin, Wenyu Shao, Xin Guan, and Tao Zhang. "Integrated Simulation of CO2 Injection in Heavy Oil Reservoirs with Asphaltene Precipitation Effects." Processes 13, no. 6 (2025): 1838. https://doi.org/10.3390/pr13061838.
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The results of core flooding experiments can guide the formulation of development plans for similar oil reservoirs. However, for cores from heavy oil reservoirs, asphaltene deposition often occurs during flooding due to changes in pressure, temperature, and petroleum composition, affecting the determination of injection parameters. Taking core samples from the Xia 018 well block as the research object, this study determined that the crude oil sample exhibits normal CO2 sensitivity based on PVT experiments and core flooding results. A corresponding asphaltene precipitation model was established and coupled with core-scale numerical simulation, forming an integrated core-scale numerical simulation method considering asphaltene precipitation. Through orthogonal experimental design, the optimized fracturing production parameters for Well Y were determined as follows: fracturing stage length of 1000 m, CO2 injection volume of 100 m3 per stage, fluid volume per stage of 1000 m3, proppant volume of 1000 m3, and injection rate of 14 m3/min. Finally, the optimized parameters were applied to simulate a case well, where the asphaltene deposition model combined with pressure nephograms during production provided effective guidance on unplugging timing. Compared with results without using the asphaltene deposition model, cumulative production decreased by 1300 m3 when the model was applied. These findings can provide a reference for the development of similar reservoirs.
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Zhao, Yang, Shu Tao Lu, Han Gao, and Ying Gong. "Numerical Simulation Research on Improving Effect of Steam Flooding by Using High Permeability Belt." Applied Mechanics and Materials 483 (December 2013): 635–38. http://dx.doi.org/10.4028/www.scientific.net/amm.483.635.
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Development of the reservoir in A block of Liaohe Oilfield present compound rhythmreservoirs, high permeability layer among the reservoir, according to the realsituation that high permeability layer exist, for the efficient utilization of producingremaining oil by horizontal well, that need to optimize locations, trajectory, lengthof horizontal well. A fine geological model which reflects the characteristicsof the reservoir in studied area was constructed with Petrel and CMG software. Optimizelocations, trajectory, length of horizontal well and vapor injection parametersupon the history matching. The research result shows that steam override, afterreaching high permeability layer, the steam makes fast breakthrough in highpermeability layer, keeping on upward heating the reservoirs with large contactarea. Finally the reservoirs can be uniformly swept in the vertical direction. Thenumerical simulation accurately predicts the optimized horizontal well can effectiveexpoit the residual oil.
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Hossain, MB. "Effect of alternate wetting and drying versus continuous flooding on carbon rates in rice and soil." International Journal of Agricultural Research, Innovation and Technology 6, no. 1 (2016): 26–33. http://dx.doi.org/10.3329/ijarit.v6i1.29209.
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An experiment was conducted at Bangladesh Institute of Nuclear Agriculture (BINA) farm, Mymensingh, Bangladesh during 2010-2011 to find out the effect of different water and organic residue rates on rice and soil. Organic carbon rates from cow dung (0.5, 1.0, 1.5 and 2.0 t C ha-1 including control) were evaluated under alternate wetting and drying (AWD) and continuous flooding (CF). CF system in combination with chemical fertilizers and 2.0 t C ha-1 produced the maximum plant height, filled grains tiller-1, 1000 grains weight, grain and straw yields. Combined use of 2.0 t C ha-1 cow dung and CF system decreased CO2-C gas emission, increased carbon accumulation in above ground biomass of rice as well as carbon sequestration in soil. This treatment also helped to optimize soil pH. Based on these results, it may be concluded that continuous flooding system in combination 2.0 t C ha-1 increased grain yield, carbon accumulation in above ground biomass, carbon sequestration in soil and optimized soil pH.Int. J. Agril. Res. Innov. & Tech. 6 (1): 26-33, June, 2016
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Ma, Kui-qian, Hai-chao Feng, Dong Liu, Jie Tan, and Qin Zhu. "Experimental Study on Factors Influencing the Efficiency of Hot Water Injection in Offshore Heavy Oil Reservoirs." Journal of Physics: Conference Series 2834, no. 1 (2024): 012096. http://dx.doi.org/10.1088/1742-6596/2834/1/012096.
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Abstract In response to the problem of low final recovery rate in conventional water flooding development of offshore heavy oil, the Bohai LD5 heavy oil field was taken as the target area. Through one-dimensional oil displacement efficiency experiments, the influence of crucial injection and production parameters on oil displacement efficiency, such as temperature, injection rate, injection production ratio, timing of hot water flooding, and injection medium, was studied. The key injection and production parameters were optimized, and the main controlling factors affecting the efficiency of hot water flooding after water flooding were identified through data analysis. Propose an optimization approach for thermal injection media and quantitatively evaluate the oil recovery efficiency under different injection and production parameters. Research has shown that for the Bohai LD5 heavy oil field, the optimal combination of injection and production parameters is: an injection rate of 2mL/min, injection temperature of 110°C, and timing of conversion to flooding at a recovery rate of 20% to 30% (water content of 55% to 70%). The hot water composite flue gas has the best oil recovery effect, considering both oil recovery efficiency and on-site construction conditions. The degree of influence of various factors on the efficiency of hot water flooding is as follows: temperature>timing of hot water flooding (recovery degree)>injection rate. Under low temperature (within 110 °C) conditions, temperature is the main factor affecting the efficiency of hot water flooding. The overall recovery rate of different injection media shows a trend of hot water composite>hot water>cold recovery.
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Karambeigi, Mohammad Saber, Ali Haghighi Asl, and Masoud Nasiri. "Multi-Objective Optimization of Microemulsion Flooding for Chemical Enhanced Oil Recovery." Oil & Gas Sciences and Technology – Revue d’IFP Energies nouvelles 73 (2018): 4. http://dx.doi.org/10.2516/ogst/2017032.
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Microemulsion flooding is one of the most effective methods of Chemical Enhanced Oil Recovery (CEOR), particularly for the production of residual oil trapped in unconventional reservoirs. A critical step for successful application of this technique is to achieve a suitable formulation. Previous studies have almost focused on the technical aspects while considering both practical and economic matters as conflicting objectives has been neglected. In the present paper, the formulation of microemulsion is optimized based on the trade-off between scientific and financial responses using a hybrid workflow in which experimental design and artificial intelligence methodologies are composed. To appraise the efficiency of developed algorithm, a challenge case study is first evaluated and compared to previous approaches. Thereafter, the second case is examined in which a newly developed formulation of microemulsion for high temperature carbonate reservoirs is optimized. The outcomes of this multi-attribute workflow are compared to a single-objective algorithm. The results indicate the outstanding performance of the proposed approach for multi-objective optimization of microemulsion formulation. Eventually, the possible concerns regarding the application of microemulsion flooding in unconventional reservoirs are discussed.
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Tong, Haoyu, Yonghong Cao, and Yue Zhang. "Optimization and Evaluation of Wetland Ecological Networks for Mitigating Urban Flooding." Water 17, no. 10 (2025): 1461. https://doi.org/10.3390/w17101461.
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Innovative solutions are needed for urban flooding exacerbated by climate change. In light of this, this study developed an integrated framework for urban wetland flood control that combines Morphospatial Pattern Analysis (MSPA), minimum cumulative resistance (MCR) modeling, and complex network theory for optimizing an ecological network of flood control and mitigation wetlands in Changchun, China. The results show that the optimized ecological network significantly improved connectivity and flood mitigation efficiency. The node degree increased from 2.737 to 3.433, and the average clustering coefficient exhibited an increase from 0.074 to 0.231, enhancing material flow efficiency. Robustness analysis revealed that the optimized network’s connectivity robustness improved by 12.6%, 18.4%, and 24.1% under random, malicious, and controlled attack scenarios, respectively. Additionally, ecological corridors with a width of 30–50 m were identified as the optimal range for water conveyance potential, effectively dispersing peak runoff and reducing flood risk. This study provides both a transferable methodology for flood-resilient planning and specific policy actions, including priority conservation of high-betweenness nodes and restoration of fragmented wetlands, offering practical solutions for high-density cities facing similar climate challenges.
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Shi, Wei. "An Optimized Flooding Algorithm Based on Multipoint Relaying for Mobile Ad Hoc Networks." Journal of Computer Research and Development 44, no. 6 (2007): 924. http://dx.doi.org/10.1360/crad20070603.
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Jacobsson, Martin, Cheng Guo, and Ignas Niemegeers. "An experimental investigation of optimized flooding protocols using a wireless sensor network testbed." Computer Networks 55, no. 13 (2011): 2899–913. http://dx.doi.org/10.1016/j.comnet.2011.05.024.
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Zhao, David W., Jacky Wang, and Ian D. Gates. "Optimized solvent-aided steam-flooding strategy for recovery of thin heavy oil reservoirs." Fuel 112 (October 2013): 50–59. http://dx.doi.org/10.1016/j.fuel.2013.05.025.
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Pandey, Anurag, Syed Feraz Qamar, Sumanta Das, et al. "Advanced multi-wall carbon nanotube-optimized surfactant-polymer flooding for enhanced oil recovery." Fuel 355 (January 2024): 129463. http://dx.doi.org/10.1016/j.fuel.2023.129463.
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Haghighi, Omid, Ghasem Zargar, Abbas Khaksar Manshad, et al. "Effect of Environment-Friendly Non-Ionic Surfactant on Interfacial Tension Reduction and Wettability Alteration; Implications for Enhanced Oil Recovery." Energies 13, no. 15 (2020): 3988. http://dx.doi.org/10.3390/en13153988.
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Production from mature oil reservoirs can be optimized by using the surfactant flooding technique. This can be achieved by reducing oil and water interfacial tension (IFT) and modifying wettability to hydrophilic conditions. In this study, a novel green non-ionic surfactant (dodecanoyl-glucosamine surfactant) was synthesized and used to modify the wettability of carbonate reservoirs to hydrophilic conditions as well as to decrease the IFT of hydrophobic oil–water systems. The synthesized non-ionic surfactant was characterized by Fourier transform infrared spectroscopy (FTIR) and chemical shift nuclear magnetic resonance (HNMR) analyses. Further pH, turbidity, density, and conductivity were investigated to measure the critical micelle concentration (CMC) of surfactant solutions. The result shows that this surfactant alters wettability from 148.93° to 65.54° and IFT from 30 to 14 dynes/cm. Core-flooding results have shown that oil recovery was increased from 40% (by water flooding) to 59% (by surfactant flooding). In addition, it is identified that this novel non-ionic surfactant can be used in CO2 storage applications due to its ability to alter the hydrophobicity into hydrophilicity of the reservoir rocks.
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Mühlethaler, Paul, Éric Renault, and Selma Boumerdassi. "Design and Evaluation of Flooding-Based Location Service in Vehicular Ad Hoc Networks." Sensors 20, no. 8 (2020): 2389. http://dx.doi.org/10.3390/s20082389.
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Location-based routing protocols for vehicular ad hoc networks (VANETs) use location information to determine routing decisions. This information is provided by a location service that is queried by nodes in order to properly forward packets to communication partners. This paper presents the semiflooding location service, a proactive flooding-based location service that drastically reduces the number of update packets sent over the network compared to traditional flooding-based location services. This goal is achieved by each node partially forwarding location information. We present both deterministic and probabilistic approaches for this algorithm, which remains very simple. A mathematical model is proposed to show the effectiveness of this solution. The cases of homogeneous 1D, 2D, and 3D networks were studied for both deterministic and probabilistic forwarding decisions. We compare our algorithm with simple flooding and with the multipoint-relay (MPR) flooding of the optimized-link-state-routing (OLSR) protocol, and we show that our algorithm, despite being very simple, has excellent scalability properties. The mean number of generated messages ranges with the mean number of the neighbors of one random network node.
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Zhang, Lei, Hongen Dou, Kun Zhang, et al. "CNN-LSTM Model Optimized by Bayesian Optimization for Predicting Single-Well Production in Water Flooding Reservoir." Geofluids 2023 (May 22, 2023): 1–16. http://dx.doi.org/10.1155/2023/5467956.
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Geared toward the problems of predicting the unsteadily changing single oil well production in water flooding reservoir, a machine learning model based on CNN (convolutional neural network) and LSTM (long short-term memory) is established which realizes precise predictions of monthly single-well production. This study is considering more than 60 dynamic and static factors that affect the changes of oil well production, introduce water injection parameters into data set, select 11 main control factors, and then, build a CNN-LSTM model optimized by Bayesian optimization. The effectiveness of the proposed model is verified in a realistic reservoir. The experiment results show that the prediction accuracy of the proposed model is over 90%, which suggests a penitential application in an extensive range of applications. Production forecasting by the developed model is simple, efficient, and accurate, which can provide a guidance for the dynamic analysis of a water flooding reservoir, and work as a good reference of the development and production of other types of reservoirs.
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Widyaningsih, Ratna, Muhamad Zamzam Istimaqom, Hizballah Nidaulhaq, and Atma Budi Arta. "The Application of Diagnostic Plots to Evaluate Water Flooding." Journal of Petroleum and Geothermal Technology 1, no. 1 (2020): 36. http://dx.doi.org/10.31315/jpgt.v1i1.3323.
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To analyze production optimization using waterflood, several types of diagnostic plots are needed to determine the response to using waterflood. If you have analyzed 1 plot, it is necessary to conduct a comprehensive analysis to evaluate its success rate by combining it using another plot analysis. The X-Min Field is a field that produces light oil and is managed by the Asset Optimization SLO North PT. Chevron Pacific Indonesia. This field was discovered in 1959 and started to be produced in 1966. Currently, 100 wells have been drilled with 37 active wells from 43 production wells, active injector wells are 18 out of 19, inactive wells 30, 4 wells have been plugged in, and there are 4 active wells that produce gas. The number of OOIPs in this field is 593 MMBO with cumulative production reaching 283.7 MMBO and Recovery Factor reaching 47.7%. In 2017 it was noted that the current production in December 2017 amounted to 5,374 BOPD / 121,264 BFPD or in other words the water cut reached 96.6%. Meanwhile, the amount of injection used to optimize this field is 144,103 BWIPD. Reservoirs in this field have 4 reservoirs namely Res-1, Res-2, Res-3, and Res-4 wherein each reservoir there are several grains of sand optimized using waterflood. There was 8 sand analyzed, including Sand Asyique, Sand Bajubaru, Sand Cemangad, Sand Emakpintar, Sand Fantamantap, Sand Gulungulung, Sand Harikita, and Special Sand. Closes the producer indicated premature water breakthrough. General recommendations given to various sands include adding or subtracting, both injectors and producers based on the response of each sand to water flooding.
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Islam Khan, Md Ashraful, Sander Haaland Kleiberg, Ivan Dario Pinerez Torrijos, Tina Puntervold, and Skule Strand. "Carbonated Smart Water Injection for Optimized Oil Recovery in Chalk at High Temperature." E3S Web of Conferences 367 (2023): 01008. http://dx.doi.org/10.1051/e3sconf/202336701008.
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Finding cost-efficient ways of increasing oil production with a low carbon footprint is the new challenge for the petroleum industry that wants to meet the net-zero emission goals by 2050. Smart water injection is an EOR process that increases oil production and delays water breakthrough by wettability alteration. Seawater is a smart water in chalk reservoirs, being especially effective at high temperatures. Different studies have shown that the effectiveness of seawater can be further improved by modifying the ion composition before injection. Carbonated water (CW) has been proposed as a potential EOR fluid. In addition to producing extra oil, the reduction of greenhouse gas (CO2) in the atmosphere can be achieved by using carbonated smart water as an injection fluid. The main mechanism behind increased oil recovery by injecting carbonated water is believed to be oil viscosity reduction and swelling, as the CO2 is transferred from the aqueous phase to the oil phase. Wettability alteration has also been proposed as a possible mechanism, and this hypothesis is further investigated in this study along with other proposed mechanisms. Stevns Klint outcrop chalk was used in this study, this material is recognized as an excellent analogue for North Sea chalk reservoirs. Optimized oil recovery by carbonated water in chalk was investigated at a high temperature (130°C) by flooding carbonated formation water (CFW) and carbonated seawater (CSW), to be compared with high saline formation water (FW) and seawater (SW) flooding. The oil/brine/rock/CO2 interactions were tracked by measuring the pH of the produced water (PW) and by identifying any mineralogical changes by SEM (Scanning Electron Microscope) and EDX (Energy Dispersive X-Ray) analyses. The solubility of CO2 in different brines was measured and compared with simulation data performed by PHREEQC. The diffusion of CO2 from the aqueous phase to the oil phase was analysed to check if enough CO2 can be diffused from the carbonated water into the oil phase. By flooding CSW in both secondary and tertiary modes, a slight increase in the oil recovery was observed and was found to be the best performing brine. The oil recovery was also slightly increased using CFW in tertiary mode after FW which does not behave like smart water for carbonates. The solubility of CO2 was low and increased by increasing pressure and decreasing brine salinity. The acidity of CW did not increase by increasing pressure. No changes in pore surface minerals were observed after CW flooding, confirming limited mineral dissolution. A mass transfer of CO2 from the brine phase to the oil phase was confirmed in the experimental work, but a significant amount of CO2 remained in the brine phase. The main mechanism behind this extra oil observed using CW is most likely not linked to oil swelling and viscosity reduction or mineral dissolution which could affect the porosity and the permeability of the rock system. Wettability alteration is a more likely explanation but needs to be looked further into for confirmation.
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Lin, Tao, Tianliang Li, Hongzhi Song, and Zhongtao Yuan. "Simulation of Multi-component Thermal Fluid Flooding in Horizontal Well of Offshore Heavy Oil Reservoirs." Journal of Physics: Conference Series 2610, no. 1 (2023): 012030. http://dx.doi.org/10.1088/1742-6596/2610/1/012030.
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Abstract After many-turns of huff and puff of multi-component thermal fluid, only the heavy oil in a limited area near the wellbore is produced. However, the inter-well areas, namely the dead oil areas, are not influenced by multi-component thermal fluid. Therefore, it is necessary to carry out the research on multi-component thermal fluid flooding. The facility of thermal recovery 3D physical stimulation is adopted to carry out simulation of flooding in various well spacing of pseudo-line well pattern, and producer-injector spacing and parameters are optimized with numerical simulation. The results of physical simulation and numerical simulation results show that the effect of the 250m spacing of well pattern with injectior-productor ratio 1:3 is better than other well spacing, with maximum recovery of 56.02%. The research results provide a technical support for the offshore multi-component thermal fluid flooding experiment.
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Huang, Bin, Jie Wang, Wei Zhang, Cheng Fu, Ying Wang, and Xiangbin Liu. "Screening and Optimization of Demulsifiers and Flocculants Based on ASP Flooding-Produced Water." Processes 7, no. 4 (2019): 239. http://dx.doi.org/10.3390/pr7040239.
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The water produced by alkaline–surfactant–polymer (ASP) flooding is difficult to treat due to the presence of residual chemicals. Therefore, research and development of efficient and low-cost methods for the treatment of ASP flooding produced water is necessary. Chemical destabilization is the most common and effective way to treat the produced water. This paper describes an optimization method for demulsification and flocculation. Some demulsifiers and flocculants commonly used in oilfields were screened, compounded, and optimized. Since the effect of treatment using only demulsifier or flocculant to treat the produced water is often not enough to meet the reinjection standard, an orthogonal experiment was carried out to study the demulsification–flocculation method to treat produced water. Five main influencing factors of the oil concentration were investigated. Based on the results of the range analysis and the relationship between the five factors and oil concentration, the order of significant factors was found to be demulsifier dosage > flocculant dosage > settling time > stirring time > stirring intensity, and the optimal demulsification–flocculation treatment conditions were successfully optimized.
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Tang, Xiujun, Xiao Li, Chen Yang, and Ling Li. "Study on the Adaptability of Jurassic Nitrogen Foam Cone Pressing." E3S Web of Conferences 406 (2023): 02005. http://dx.doi.org/10.1051/e3sconf/202340602005.
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Aiming at the problems of bottom water coning and oil well flooding caused by the large impact of the early production strength of the Jurassic bottom water direct contact well in the Seventh Oil Production Plant. Carry out research on nitrogen foam control bottom water coning technology, mainly including: ①laboratory test to optimize foam system suitable for Jurassic system of No. 7 Oil Production Plant, determine injection concentration and optimal gas-liquid ratio; ②The nitrogen foam injection timing and shut in time were optimized by numerical simulation method; ③Summarize the field tests that have been carried out, and determine the optimal combination of parameters suitable for the Jurassic nitrogen foam pressure cone of No. 7 Oil Production Plant.
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Moodie, Andrew J., and Jeffrey A. Nittrouer. "Optimized river diversion scenarios promote sustainability of urbanized deltas." Proceedings of the National Academy of Sciences 118, no. 27 (2021): e2101649118. http://dx.doi.org/10.1073/pnas.2101649118.
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Socioeconomic viability of fluvial-deltaic systems is limited by natural processes of these dynamic landforms. An especially impactful occurrence is avulsion, whereby channels unpredictably shift course. We construct a numerical model to simulate artificial diversions, which are engineered to prevent channel avulsion, and direct sediment-laden water to the coastline, thus mitigating land loss. We provide a framework that identifies the optimal balance between river diversion cost and civil disruption by flooding. Diversions near the river outlet are not sustainable, because they neither reduce avulsion frequency nor effectively deliver sediment to the coast; alternatively, diversions located halfway to the delta apex maximize landscape stability while minimizing costs. We determine that delta urbanization generates a positive feedback: infrastructure development justifies sustainability and enhanced landform preservation vis-à-vis diversions.
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Li, Xianjie, Jian Zhang, Yaqian Zhang, et al. "Experimental Study on the Application of Polymer Agents in Offshore Oil Fields: Optimization Design for Enhanced Oil Recovery." Polymers 17, no. 2 (2025): 244. https://doi.org/10.3390/polym17020244.
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The Bohai oilfield is characterized by severe heterogeneity and high average permeability, leading to a low water flooding recovery efficiency. Polymer flooding only works for a certain heterogeneous reservoir. Therefore, supplementary technologies for further enlarging the swept volume are still necessary. Based on the concept of discontinuous chemical flooding with multi slugs, three chemical systems, which were polymer gel (PG), hydrophobically associating polymer (polymer A), and conventional polymer (polymer B), were selected as the profile control and displacing agents. The optimization design of the discontinuous chemical flooding was investigated by core flooding experiments and displacement equilibrium degree calculation. The gel, polymer A, and polymer B were classified into three levels based on their profile control performance. The degree of displacement equilibrium was defined by considering the sweep conditions and oil displacement efficiency of each layer. The effectiveness of displacement equilibrium degree was validated through a three-core parallel displacement experiment. Additionally, the parallel core displacement experiment optimized the slug size, combination method, and shift timing of chemicals. Finally, a five-core parallel displacement experiment verified the enhanced oil recovery (EOR) performance of discontinuous chemical flooding. The results show that the displacement equilibrium curve exhibited a stepwise change. The efficiency of discontinuous chemical flooding became more significant with the number of layers increasing and heterogeneity intensifying. Under the combination of permeability of 5000/2000/500 mD, the optimal chemical dosage for the chemical discontinuous flooding was a 0.7 pore volume (PV). The optimal combination pattern was the alternation injection in the form of “medium-strong-weak-strong-weak”, achieving a displacement equilibrium degree of 82.3%. The optimal shift timing of chemicals occurred at a water cut of 70%, yielding a displacement equilibrium degree of 87.7%. The five-core parallel displacement experiment demonstrated that discontinuous chemical flooding could get a higher incremental oil recovery of 24.5% compared to continuous chemical flooding, which presented a significantly enhanced oil recovery potential.
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Gong, Yugang, Xiankang Xin, Gaoming Yu, Mingcheng Ni, and Peifu Xu. "Optimization Study of Injection and Production Parameters for Shallow- and Thin-Layer Heavy Oil Reservoirs with Nitrogen Foam-Assisted Steam Flooding." Processes 11, no. 10 (2023): 2857. http://dx.doi.org/10.3390/pr11102857.
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Shallow- and thin-layer heavy oil reservoirs are characterized by their shallow burial, thin thickness, high viscosity, and scattered distribution. After years of steam injection development, several issues have emerged, including a highly comprehensive water cut in the reservoir and serious steam channeling. Therefore, there is an urgent need to change the development approach to enhance crude oil recovery. It has been discovered that developing heavy oil reservoirs through nitrogen foam-assisted steam flooding can effectively address the challenges encountered in pure steam development. This paper takes H Oilfield Block A as a case study, analyzes the geological characteristics and development status of the reservoir in this block, and predicts the recovery of steam injection development in this block using the injection-production characteristic curve method. Furthermore, by establishing a reservoir geological model and fitting it to the historical behavior of the target reservoir, the nitrogen foam-assisted steam flooding injection and production parameters were optimized. The optimal parameters are as follows: optimal steam injection intensity of 2.0 t/(d·ha·m), optimal production/injection ratio of 1.2:1, optimal nitrogen foam slug injection volume of 0.15 PV, optimal nitrogen/steam ratio of 2:1, and intermittent injection between 3 and 4 foam slugs. It is anticipated that this optimized scheme will result in a predicted increase in final recovery of 13.55%. The findings of this study hold significant importance in guiding the application of nitrogen foam-assisted steam flooding in shallow and thin heavy oil reservoirs.
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Sun, Lili, Xining Hao, Hongen Dou, Caspar Daniel Adenutsi, Zhiping Li, and Yunjun Zhang. "Co-optimization of oil recovery and CO2 storage for cyclic CO2 flooding in ultralow permeability reservoirs." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 73 (2018): 42. http://dx.doi.org/10.2516/ogst/2018041.
Full textAbstract:
Cyclic CO2 flooding is an efficient method to enhance oil recovery in ultralow permeability reservoirs. As the demand for low carbon economy development, co-optimization of CO2 storage and utilization should be considered. In this research, initially a comprehensive optimization method was proposed, which co-optimize oil recovery and CO2 storage by different weighting factors. Then, a series of core flooding experiments were performed using the core samples collected from Changqing oilfield, which is a ultralow permeability reservoir with heterogeneity and micro-cracks, CO2 injection parameters of slug size and Injection-Soaking Time Ratio (ISR) were optimized. The results revealed that the optimal injection parameters changed for different optimization objectives. In the case where equal important to oil recovery and CO2 storage were considered, the optimum CO2 injection parameters in the ultralow permeability reservoirs were 0.03PV for slug size and 1:1 for ISR. Comparing the method of oil recovery optimization (ω 1 = 1) to co-optimization of oil recovery and CO2 storage (ω 1 = ω 2 = 0.5), oil recovery was reduced by 8.93%, CO2 storage was significantly increased by 25.85%. The results provide an insight into parameter optimization of CO2 enhanced oil recovery design.
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Lan, Yu Bo, and Qi Li. "Practical Adjustment of Stratum Series for S Oilfield." Advanced Materials Research 1073-1076 (December 2014): 2210–14. http://dx.doi.org/10.4028/www.scientific.net/amr.1073-1076.2210.
Full textAbstract:
In S Development Area, the production targets of each well net went bad and had interleaved distributions with old well patterns. Meanwhile, polymer flooding well patterns made the conflict of cohesion and dynamic regulation outstanding. Especially, Bei block, first using infill drilling modification, however, had troubles in extra high water period, such as long section of perforation, obvious inconsistencies between formations and high water of layers, which brought difficulties to dynamically adjusting. We selected 1.30 km2 west blocks in Bei block, made tests about sediment group restructuring to improve water flooding development effect, redistributed the series of strata and redistributed the flooding network according to the characteristics of development between the layers, combined comprehensive consideration with follow-up adjustment, such as primary network, injection production system and typed II reservoir the tertiary oil production, optimized the layers combination and well patterns arrangement, finally formed technical ideas of high water cut layers adjustment and well nets evolution.