Transient pressure analysis of fractured well in bi-zonal gas reservoirs

Zhao, Yulong; Zhang, Liehui; Liu, Yonghui; Hu, Shuyong; Liu, Qiguo

doi:10.1016/j.jhydrol.2015.02.006

Cited by 39 publications

(7 citation statements)

References 22 publications

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“…Existing in rock matrix and fractures, natural gas in shale formation is commonly described by dual-porosity models. According to the previous theoretical research and field tests [1,[3][4][5][6][7][8][9], an identical conclusion has been reached that both hydraulic fractures and natural fractures play important roles in production performance in shale gas reservoirs.…”

Section: Introductionmentioning

confidence: 72%

Production Behavior of Fractured Horizontal Well in Closed Rectangular Shale Gas Reservoirs

Liu

Wang

et al. 2016

Mathematical Problems in Engineering

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This paper established a triple porosity physical model in rectangular closed reservoirs to understand the complex fluid flowing mechanism and production behavior of multifractured horizontal wells in shale gas reservoirs, which is more appropriate for practical situation compared with previous ones. According to the seepage theory considering adsorption and desorption process in stable state, the gas production rate of a well producing at constant wellbore pressure was obtained by utilizing the methods of Green’s and source function theory and superposition principle. Meanwhile, the volume of adsorbed gas (GL) and the number of hydraulic fractures (M) as well as permeabilities of matrix system (km) and microfractures (kf) were discussed in this paper as sensitive factors, which have significant influences on the production behavior of the wells. The bigger the value ofGLis, the larger the well production rate will be in the later flowing periods, and the differences of production rate with the increasing ofMare small, which manifest that there is an optimumMfor a given field. Therefore, the study in this paper is of significant importance to understand the dynamic production declining performance in shale gas reservoirs.

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Section: Introductionmentioning

confidence: 72%

Production Behavior of Fractured Horizontal Well in Closed Rectangular Shale Gas Reservoirs

Liu

Wang

et al. 2016

Mathematical Problems in Engineering

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“…Recently, some complex geometry shape models were also established to satisfy the complex geometry after fracturing in tight/oil reservoir. Jiang et al (2014) and Zhao et al (2015) established the circle composite reservoir model. This model assumes that there are two regions in reservoir.…”

Section: Introductionmentioning

confidence: 99%

“…The source function was used to solve the models. PTA and rate transient analysis (RTA) were analyzed in detail (Jiang et al, 2014;Zhao et al, 2014Zhao et al, , 2015. Similarly, Ketineni and Ertekin (2012) established the composite model for multi-stage hydraulically fractured horizontal well in a naturally fractured reservoir considering the stimulated reservoir volume (SRV).…”

Section: Introductionmentioning

confidence: 99%

A new production prediction model for multistage fractured horizontal well in tight oil reservoirs

Zhao¹,

Du²

2020

Adv. Geo-Energy Res.

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To better evaluate the production performance of tight oil reservoirs, it is urgent to solve the multistage fractured horizontal well production enigma. It is paramount to develop new models to analyze the well performance for tight oil reservoirs. In this paper, a new production prediction model of multistage fractured horizontal well in tight oil reservoir was established. In this model, unsteady transfer flow between fracture and matrix was considered. This model was solved by using Laplace transform method, line source function and Stehfest method comprehensively. The production prediction type curves including pressure transient analysis curves and rate transient analysis curves were then obtained. According to these type curves, eight flow regimes were obtained as early wellbore storage period, skin factor period, bi-linear flow regime, linear flow regime, first radial flow regime, transition flow regime, transfer flow regime and later radial flow regime. In the end, a field case history matching result was given and four key parameters' effect on tight formation well production was analyzed. This research is of both theoretical significance and practical value for tight oil development.

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“…Combining the advantages of the aforementioned two models, the latest development is to combine the dualporosity model and the HF model (Zhao et al, 2014;Zhao et al, 2015;Chen et al, 2016;Jia et al, 2016Morteza et al, 2018). Such combined models can not only accurately describe fluid flow within the HFs at different angles, but also consider the contribution of the secondaryfracture networks (Ren et al, 2016;Chen et al, 2017b).…”

Section: Introductionmentioning

confidence: 99%

Effect of Stress-Sensitive Fracture Conductivity on Transient Pressure Behavior for a Multi-Well Pad With Multistage Fractures in a Naturally Fractured Tight Reservoir

Meng

Tan

et al. 2020

Front. Energy Res.

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This paper presents a semianalytical solution for evaluating transient pressure behavior of a multi-well pad with multistage fractures in a naturally fractured tight reservoir by considering the stress-sensitive effect imposed by both natural and hydraulic fractures. More specifically, the model pertaining to matrix/natural fractures is considered as a dual-porosity continuum, while its analytical flow model can be obtained by use of a slab-source function in the Laplace domain. The hydraulic fracture model is solved by discretizing each fracture into small segments to describe the flow behavior, while stress sensitivity in both the natural fracture (NF) subsystem and hydraulic fracture (HF) subsystem has been taken into account. To validate the newly developed semianalytical model, its solution has been obtained and compared with those of a commercial numerical simulator. By generating the type curves, there may exhibit eight flow regimes: pure wellbore storage, skin effect transition flow, linear flow regime within HFs, early radial flow, biradial flow, transition flow, pseudo-steady diffusion, and the late-time pseudo-radial flow. Furthermore, late-time flow regimes are found to be significantly distorted by the multi-well pressure interference. The smaller the well-rate ratio is, the more distorted the pressure and pressure derivative curves will be. In addition, well spacing and fracture length are found to dominate the flow behavior when multi-well pressure interference occurs. As the well spacing is decreased, the fracture length is increased, and thus occurrence of multi-well pressure interference is initiated earlier. Permeability moduli of NFs and HFs impose no impact on the multi-well pressure interference; however, it can distort flow regimes, leading to a severe distortion of pressure and pressure derivative curves. Similarly, the effect of HF permeability modulus on the flow in a hydraulic fracture, the minimum fracture conductivity is another key factor affecting the “hump” on the pressure curve. As the crossflow coefficient is increased, flow exchange between matrix and NFs is increased. With an increase in the storage ratio, flow exchange lasts longer and the second “dip” on the pressure curve becomes deeper.

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Transient pressure analysis of fractured well in bi-zonal gas reservoirs

Cited by 39 publications

References 22 publications

Production Behavior of Fractured Horizontal Well in Closed Rectangular Shale Gas Reservoirs

Production Behavior of Fractured Horizontal Well in Closed Rectangular Shale Gas Reservoirs

A new production prediction model for multistage fractured horizontal well in tight oil reservoirs

Effect of Stress-Sensitive Fracture Conductivity on Transient Pressure Behavior for a Multi-Well Pad With Multistage Fractures in a Naturally Fractured Tight Reservoir

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