Flood pattern optimization of horizontal well injection

Ling, Zong-fa; Lijuan, Wang; Hu, Yongle; Li, Baozhu

doi:10.1016/s1876-3804(08)60013-0

Cited by 14 publications

(6 citation statements)

References 12 publications

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“…Based on P 1 and P 2 , the bottomhole pressures P wf1 and P wf2 can be found according to equation (1).…”

Section: Theoretical Deductionmentioning

confidence: 99%

“…In the process of carrying out a certain operation in the same-well injection and production wells, due to the higher pressure of the injected layer section, there is a certain pressure difference between the injected layer and the wellbore, so part of the injected water of the injected layer section flows backwards into the wellbore, while the formation pressure of the extracted layer section is lower than the wellbore pressure, and there is also a certain pressure difference between the wellbore and the extracted layer section, therefore, the produced water layer seeps into a part of the wellbore water [1][2][3] . This leads to the fact that the amount of water injected into the well after the operation is often larger than the actual amount of water injected to make up for the pressure deficit in the formation, but since this process occurs simultaneously in the wellbore, it is not possible to monitor the actual amount of water coming in and out of the formation, so the actual amount of water injected after the operation is difficult to predict, and it is not possible to judge the impact of this operation on the production capacity of the formation and the ability of the formation to absorb the water [4][5][6] .…”

Section: Introductionmentioning

confidence: 99%

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The methodology for calculating the apparent water absorption index from test injection data

2024

E3S Web Conf.

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After the oilfield enters the medium-high water content period, the treatment problem of produced water becomes more and more prominent, and the same-well injection technology can realize the oil-water separation of the produced fluid at the well. The separated water is injected back into the oil reservoir by the injection pump, while the oil-water mixture with higher oil content is lifted to the surface by the extraction pump. However, once the tampering operation is carried out on the production layer, the fluid production capacity of the layer cannot be judged, and it is impossible to determine the reasonable production allocation of the injection and recovery layer. Moreover, in the normal production process, the production tubing can not be taken out normally, so it is difficult to determine the production capacity after blocking by logging method. Therefore, it is necessary to carry out theoretical research on the production capacity of the same injection and recovery wells after tampering according to the method of reservoir engineering, so as to provide a theoretical basis for the reasonable production allocation in the field.

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“…Based on P 1 and P 2 , the bottomhole pressures P wf1 and P wf2 can be found according to equation (1).…”

Section: Theoretical Deductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

The methodology for calculating the apparent water absorption index from test injection data

2024

E3S Web Conf.

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show abstract

“…A reservoir model has been built in the STARS black-oil simulator (Computer Modelling Group, Calgary, AB, Canada) for a field scale of 600ˆ600ˆ68 ft 3 with 15ˆ15ˆ8 gridblocks in Cartesian coordinates. A large area between horizontal wells is recommended as a result of achieving better economic terms due to the efficiency of controlling the operated wells [16]. The reservoir porosity is assumed to be constant over the reservoir; however, the permeability changes vertically, corresponding to different layers.…”

Section: Reservoir Descriptionmentioning

confidence: 99%

The Performance of Surfactant-Polymer Flooding in Horizontal Wells Consisting of Multilayers in a Reservoir System

Van

Chon

2016

Energies

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Surfactant-polymer (SP) flooding has been demonstrated to be an effective method to recover oil in the enhanced oil recovery (EOR) stage when water flooding is no longer relevant. Theoretically, adding surfactant causes the reduction of the interfacial tension between oil and water in pores, therefore reducing the residual oil saturation, whereas the sweep efficiency will be significantly improved by the polymer injection as a result of proper mobility control. With regard to the well patterns, water flooding has demonstrated a high productivity in horizontal wells. Recently, other EOR processes have been increasingly applied to the horizontal wells in various well patterns. In this study, the efficiency of SP flooding applied to horizontal wells in various well configurations is investigated in order to select the best EOR performance in terms of either a technical or economical point of view. Furthermore, the reservoir is assumed to be anisotropic with four different layers that have same porosity but different permeability between each layer. The study figures out that, the utilization of a horizontal injector and producer always gives a higher oil production in comparison with the reference case of a conventional vertical injector and producer; however, the best EOR performances that demonstrate the higher oil recovery and lower fluid injected volume than those of the reference case are achieved when the production well is located in bottom layers and parallel with the injection well at a distance. While the location of producer decides oil productivity, the location of injector yet affects the uniformity of fluids propagation in the reservoir. A predefined feasibility factor is also taken into consideration in order to reject the infeasible cases that might give a high oil production but require a higher injected volume than the reference case. This factor is used as an economic parameter to evaluate the success of the EOR performance. The simulation is carried out in a quarter five-spot pattern reservoir with the support of the Computer Modeling Group (CMG) simulator. Understanding the predominant EOR performance of SP flooding in horizontal wells will help to select the best plan to obtain the highest oil recovery when considering economic issues.

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“…In the process of horizontal well network deployment, the effect of natural cracks and hydraulic cracks on the well network should be fully considered. According to domestic well network experience in low permeability reservoirs, the orientation of water injection well alignment should be deployed parallel to the orientation of maximum horizontal principle stress as far as possible to achieve better water flood development effect [4][5][6] . Due to the well location difference, maximum principle stress orientation, and crack orientation, the influence of hydraulic fracturing on development performance is also different.…”

Section: Introductionmentioning

confidence: 99%

Mixed Horizontal Well Pattern and Fracturing Parameter Optimization of Low Permeability Reservoir

Hu,

Guo,

Cao

et al. 2023

J. Phys.: Conf. Ser.

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Horizontal well fracturing development is significant in improving the development effect of low permeability reservoirs and is widely applied in many low permeability reservoirs of China. In this study, the reservoir numerical simulation is used to establish different mixed horizontal well networks of the target reservoir. The result shows that the best waterflood development effect is achieved when horizontal segment orientation and crack orientation are at an angle of 45°. The horizontal segment length and fracturing parameters of mixed horizontal well networks are optimized. It is considered that the rational horizontal segment length of the horizontal well is 400 m, the rational number of cracks is 3, and the optimal crack conductivity is between 180-200 mD.m. Through the study of mixed horizontal well network and fracturing parameter optimization, the low permeability reservoir efficient horizontal well fracturing development is well guided.

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Flood pattern optimization of horizontal well injection

Cited by 14 publications

References 12 publications

The methodology for calculating the apparent water absorption index from test injection data

The methodology for calculating the apparent water absorption index from test injection data

The Performance of Surfactant-Polymer Flooding in Horizontal Wells Consisting of Multilayers in a Reservoir System

Mixed Horizontal Well Pattern and Fracturing Parameter Optimization of Low Permeability Reservoir

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