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Yuewu Liu
Institute of Mechanics Chinese Academy of Sciences Beijing China

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Research article
Published: 01 May 2020 in Energy Science & Engineering
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Shale gas plays a crucial role in the national energy supply. However, fast pressure drop, production decline, and water resources pollution caused by well interference and fracture hits become more severe in multi‐layer mining shale gas fields. Such as, it is urgent to evaluate the interference of multi‐stage fracturing horizontal wells (MFHWs) between the upper and lower gas layers in Chinese Jiaoshiba shale gas field. Therefore, we put forward a comprehensive method to analyze the MFHW interference in this paper. The method contains bottom‐hole pressure response analysis (BHPRA) during neighboring well fracturing, BHPRA of well interference test, and production dynamic analysis. Our study indicates that longitudinal pressure interference exists between the Jiaoshiba upper and lower gas layers upon the apparent interference pressure response in a multi‐well test. However, MFHW interferences occur in the corresponding fracturing stages with shorter distance, and the interference strength is related to both well distance and fracturing scales. The Jiaoshiba upper gas layers can be developed to increase the gas production performance, but it is necessary to maintain a reasonable well spacing to avoid severe interference during the development.

ACS Style

Dapeng Gao; Yuewu Liu; Songqi Pan; Jue Wang; Xinmao Zhou. Longitudinal interference analysis of shale gas multi‐stage fracturing horizontal wells upon high‐precision pressure test. Energy Science & Engineering 2020, 8, 2387 -2401.

AMA Style

Dapeng Gao, Yuewu Liu, Songqi Pan, Jue Wang, Xinmao Zhou. Longitudinal interference analysis of shale gas multi‐stage fracturing horizontal wells upon high‐precision pressure test. Energy Science & Engineering. 2020; 8 (7):2387-2401.

Chicago/Turabian Style

Dapeng Gao; Yuewu Liu; Songqi Pan; Jue Wang; Xinmao Zhou. 2020. "Longitudinal interference analysis of shale gas multi‐stage fracturing horizontal wells upon high‐precision pressure test." Energy Science & Engineering 8, no. 7: 2387-2401.

Journal article
Published: 15 January 2019 in Energies
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After the large-scale horizontal well pattern development in shale gas fields, the problem of fast pressure drop and gas well abandonment caused by well interference becomes more serious. It is urgent to understand the downhole transient pressure and flow characteristics of multi-stage fracturing horizontal well (MFHW) with interference. Therefore, the reservoir around the MFHW is divided into three regions: fracturing fracture, Stimulated reservoir volume (SRV), and unmodified matrix. Then, multi-region coupled flow model is established according to reservoir physical property and flow mechanism of each part. The model is numerically solved using the perpendicular bisection (PEBI) grids and the finite volume method. The accuracy of the model is verified by analyzing the measured pressure recovery data of one practical shale gas well and fitting the monitoring data of the later production pressure. Finally, this model is used to analyze the effects of factors, such as hydraulic fractures’ connectivity, well distance, the number of neighboring wells and well pattern arrangement, on the transient pressure and seepage characteristics of the well. The study shows that the pressure recovery double logarithmic curves fall in later part when the well is disturbed by a neighboring production well. The earlier and more severe the interference, the sooner the curve falls off and the larger the amplitude shows. If the well distance is closer, and if there are more neighboring wells and interconnected corresponding fracturing segments, the more severe interference appears among the wells. Moreover, the well interference may still exist even without interlinked fractures or SRV. Especially, severe interference will affect production when the hydraulic fractures are connected directly, and the interference is weaker when only SRV induced fracture network combined between wells, which is beneficial to production sometimes. When severe well interference occurs, periodic well shut-in is needed to help restore the reservoir pressure and output capacity. In the meanwhile, the daily output should be controlled reasonably to prolong the stable production time. This research will help to understand the impact of well interference to gas production, and to optimize the well spacing and achieve satisfied performance.

ACS Style

Dapeng Gao; Yuewu Liu; Daigang Wang; Guofeng Han. Numerical Analysis of Transient Pressure Behaviors with Shale Gas MFHWs Interference. Energies 2019, 12, 262 .

AMA Style

Dapeng Gao, Yuewu Liu, Daigang Wang, Guofeng Han. Numerical Analysis of Transient Pressure Behaviors with Shale Gas MFHWs Interference. Energies. 2019; 12 (2):262.

Chicago/Turabian Style

Dapeng Gao; Yuewu Liu; Daigang Wang; Guofeng Han. 2019. "Numerical Analysis of Transient Pressure Behaviors with Shale Gas MFHWs Interference." Energies 12, no. 2: 262.

Journal article
Published: 08 January 2019 in Applied Sciences
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Pressure communication between adjacent wells is frequently encountered in multi-stage hydraulic fractured shale gas reservoirs. An interference test is one of the most popular methods for testing the connectivity of a reservoir. Currently, there is no practical analysis model of an interference test for wells connected by large fractures. A one-dimensional equation of flow in porous media is established, and an analytical solution under the constant production rate is obtained using a similarity transformation. Based on this solution, the extremum equation of the interference test for wells connected by a large fracture is derived. The type-curve of pressure and the pressure derivative of an interference test of wells connected by a large fracture are plotted, and verified against interference test data. The extremum equation of wells connected by a large fracture differs from that for homogeneous reservoirs by a factor 2. Considering the difference of the flowing distance, it can be concluded that the pressure conductivity coefficient computed by the extremum equation of homogeneous reservoirs is accurate in the order of magnitude. On the double logarithmic type-curve, as time increases, the curves of pressure and the pressure derivative tend to be parallel straight lines with a slope of 0.5. When the crossflow of the reservoir matrix to the large fracture cannot be ignored, the slope of the parallel straight lines is 0.25. They are different from the type-curves of homogeneous and double porosity reservoirs. Therefore, the pressure derivative curve is proposed to diagnose the connection form of wells.

ACS Style

Guofeng Han; Yuewu Liu; Wenchao Liu; Dapeng Gao. Investigation on Interference Test for Wells Connected by a Large Fracture. Applied Sciences 2019, 9, 206 .

AMA Style

Guofeng Han, Yuewu Liu, Wenchao Liu, Dapeng Gao. Investigation on Interference Test for Wells Connected by a Large Fracture. Applied Sciences. 2019; 9 (1):206.

Chicago/Turabian Style

Guofeng Han; Yuewu Liu; Wenchao Liu; Dapeng Gao. 2019. "Investigation on Interference Test for Wells Connected by a Large Fracture." Applied Sciences 9, no. 1: 206.

Journal article
Published: 08 November 2018 in Sustainability
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Coalbed Methane (CBM) has become an important gas resource in recent decades. The brittle property of coal matrix and overactive operation make the migration of coal fines inevitable. Blockage by coal fines that plugs flow paths is a non-negligible issue that results in a significant decline in gas production. By setting different experimental conditions with the following factors—coal fines concentration of the mixture displacing fluids, constant flow pump rate, inlet pressure, outlet pressure and confining pressure—six experimental schemes were designed to investigate the two-phase water and coal fines flow in natural core samples. When the differential pressure and flooding flow reach a pseudo-steady status, the equivalent permeability of coal samples can be approximately calculated considering coal fines migration. Furthermore, the influences of coal fines migration on the cleat opening and permeability variation are analyzed in the porous coal medium. The study will benefit CBM development and save pump maintenance costs. In this work, we found that maintaining the differential pressure for a longer period may result in new cleat openings and severe coal rock damage during the single-phase water flooding process. While coal fines may plug some natural cleats and pores, especially in the core samples with micro-cleats during the two-phase flooding stage, coal fines migration significantly reduces the equivalent permeability and dewatering ability of the coal rock in the earlier flooding. While enlarging the differential pressure in two-phase water and fines flooding, breakthrough of coal fines from the samples contributes to widened cleats. While coal fines are difficult to flood into the core pores for low-permeability core samples, coal fines gather in the inlet, and it is also difficult to reach the pseudo-steady status even under higher differential pressure. The damage to permeability mainly occurs in the early stage of coal fines migration, and an abrupt increase in the flow velocity can damage reservoirs and induce substantial coal fines generation. Thus, maintaining a stable effective strength and a controlled depressurization rate during drainage can effectively constrain coal fines output and decrease permeability damage within coal reservoirs.

ACS Style

Dapeng Gao; Yuewu Liu; Tianjiao Wang; Daigang Wang. Experimental Investigation of the Impact of Coal Fines Migration on Coal Core Water Flooding. Sustainability 2018, 10, 4102 .

AMA Style

Dapeng Gao, Yuewu Liu, Tianjiao Wang, Daigang Wang. Experimental Investigation of the Impact of Coal Fines Migration on Coal Core Water Flooding. Sustainability. 2018; 10 (11):4102.

Chicago/Turabian Style

Dapeng Gao; Yuewu Liu; Tianjiao Wang; Daigang Wang. 2018. "Experimental Investigation of the Impact of Coal Fines Migration on Coal Core Water Flooding." Sustainability 10, no. 11: 4102.

Journal article
Published: 13 July 2018 in Water
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Different from the conventional gas reservoir, coalbed methane is developed mainly by water drainage, which leads methane desorption after reservoir pressure drop. Water drainage at a reasonable speed in the early development stage is the key for enhancing later gas performance. Therefore, the investigation radius, which reflects the pressure drop region scale, is studied by deconvolution well-test to find the reasonable water drainage speed in the early period. First, the early production data (well-bottom pressure and water rate) are processed by deconvolution algorithm, and then the pressure data under unit rate is obtained to invert the comprehensive reservoir permeability and investigation radius. This deconvolution method can save the cost of the conventional well-test, and avoid reservoir damage caused by frequent well shut-off. The feasibility of the deconvolution test method is verified by comparing its interpretation results with those of the conventional pressure drop/build-up test. For a field application, the 29 wells’ comprehensive permeability are inverted by the deconvolution well-test using early water production data of Hancheng block. Furthermore, their investigation radius and pressure drawdown gradient are calculated, and the performance optimization is determined by relationship analysis between working fluid level and steady gas production rate. We find that well-bottom pressure and reservoir pressure should decrease steadily in the early development stage, with the working fluid level declining less than 1 m/d (1 m per day) in wellbore, and the pressure drawdown gradient declining less than 2.8 MPa/100 m.

ACS Style

Dapeng Gao; Yuewu Liu; Zhidong Guo; Jun Han; Jingde Lin; Huijun Fang; Hailing Ma; Sang-Bing Tsai. A Study on Optimization of CBM Water Drainage by Well-Test Deconvolution in the Early Development Stage. Water 2018, 10, 929 .

AMA Style

Dapeng Gao, Yuewu Liu, Zhidong Guo, Jun Han, Jingde Lin, Huijun Fang, Hailing Ma, Sang-Bing Tsai. A Study on Optimization of CBM Water Drainage by Well-Test Deconvolution in the Early Development Stage. Water. 2018; 10 (7):929.

Chicago/Turabian Style

Dapeng Gao; Yuewu Liu; Zhidong Guo; Jun Han; Jingde Lin; Huijun Fang; Hailing Ma; Sang-Bing Tsai. 2018. "A Study on Optimization of CBM Water Drainage by Well-Test Deconvolution in the Early Development Stage." Water 10, no. 7: 929.

Journal article
Published: 18 April 2016 in Applied Mathematics and Mechanics
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Based on the characteristics of fractures in naturally fractured reservoir and a discrete-fracture model, a fracture network numerical well test model is developed. Bottom hole pressure response curves and the pressure field are obtained by solving the model equations with the finite-element method. By analyzing bottom hole pressure curves and the fluid flow in the pressure field, seven flow stages can be recognized on the curves. An upscaling method is developed to compare with the dual-porosity model (DPM). The comparisons results show that the DPM overestimates the inter-porosity coefficient λ and the storage factor ω. The analysis results show that fracture conductivity plays a leading role in the fluid flow. Matrix permeability influences the beginning time of flow from the matrix to fractures. Fractures density is another important parameter controlling the flow. The fracture linear flow is hidden under the large fracture density. The pressure propagation is slower in the direction of larger fracture density.

ACS Style

Yizhao Wan; Yuewu Liu; Weiping Ouyang; Guofeng Han; Wenchao Liu. Numerical investigation of dual-porosity model with transient transfer function based on discrete-fracture model. Applied Mathematics and Mechanics 2016, 37, 611 -626.

AMA Style

Yizhao Wan, Yuewu Liu, Weiping Ouyang, Guofeng Han, Wenchao Liu. Numerical investigation of dual-porosity model with transient transfer function based on discrete-fracture model. Applied Mathematics and Mechanics. 2016; 37 (5):611-626.

Chicago/Turabian Style

Yizhao Wan; Yuewu Liu; Weiping Ouyang; Guofeng Han; Wenchao Liu. 2016. "Numerical investigation of dual-porosity model with transient transfer function based on discrete-fracture model." Applied Mathematics and Mechanics 37, no. 5: 611-626.

Article
Published: 16 May 2014 in Applied Mathematics and Mechanics
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A new well test model is developed for the hydraulic fractured well in coalbed by considering the following aspects: methane desorption phenomena, finite conductivity vertical fractures, and asymmetry of the fracture about the well. A new parameter is introduced to describe the storage of the fracture, which is named as a combined fracture storage. Another new concept called the fracture asymmetry coefficient is used to define the asymmetry of the fracture about the well. Finite element method (FEM) is used to solve the new mathematical model. The well test type curves and pressure fields are obtained and analyzed. The effects of the combined fracture storage, desorption factor, fracture conductivity, and fracture asymmetry coefficient on the well test type curves are discussed in detail. In order to verify the new model, a set of field well test data is analyzed.

ACS Style

Yue-Wu Liu; Wei-Ping Ou-Yang; Pei-Hua Zhao; Qian Lu; Hui-Jun Fang. Numerical well test for well with finite conductivity vertical fracture in coalbed. Applied Mathematics and Mechanics 2014, 35, 729 -740.

AMA Style

Yue-Wu Liu, Wei-Ping Ou-Yang, Pei-Hua Zhao, Qian Lu, Hui-Jun Fang. Numerical well test for well with finite conductivity vertical fracture in coalbed. Applied Mathematics and Mechanics. 2014; 35 (6):729-740.

Chicago/Turabian Style

Yue-Wu Liu; Wei-Ping Ou-Yang; Pei-Hua Zhao; Qian Lu; Hui-Jun Fang. 2014. "Numerical well test for well with finite conductivity vertical fracture in coalbed." Applied Mathematics and Mechanics 35, no. 6: 729-740.