Production Decline Analysis for Two-Phase Flow in Multifractured Horizontal Well in Shale Gas Reservoirs

Xie, Weiyang; Li, Xiaoping; Zhang, Liehui; Tan, Xiaohua; Wang, Junchao; Wang, Haitao

doi:10.1155/2015/212103

Cited by 4 publications

(3 citation statements)

References 31 publications

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“…In most cases, these flowback data are ignored if singlephase flow is used for the prediction of shale gas production [10][11][12]. This ignorance of two-phase flowback makes the predicted gas production curve inconsistent with the actual field observation in the early period [13]. In this paper, the two-phase flow in the fractured zone and hydraulic fractures is studied through our fully coupled model.…”

Section: Introductionmentioning

confidence: 99%

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A Two-Phase Flowback Model for Multiscale Diffusion and Flow in Fractured Shale Gas Reservoirs

Wang

Gao

et al. 2018

Geofluids

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A shale gas reservoir is usually hydraulically fractured to enhance its gas production. When the injection of water-based fracturing fluid is stopped, a two-phase flowback is observed at the wellbore of the shale gas reservoir. So far, how this water production affects the long-term gas recovery of this fractured shale gas reservoir has not been clear. In this paper, a two-phase flowback model is developed with multiscale diffusion mechanisms. First, a fractured gas reservoir is divided into three zones: naturally fractured zone or matrix (zone 1), stimulated reservoir volume (SRV) or fractured zone (zone 2), and hydraulic fractures (zone 3). Second, a dual-porosity model is applied to zones 1 and 2, and the macroscale two-phase flow flowback is formulated in the fracture network in zones 2 and 3. Third, the gas exchange between fractures (fracture network) and matrix in zones 1 and 2 is described by a diffusion process. The interactions between microscale gas diffusion in matrix and macroscale flow in fracture network are incorporated in zones 1 and 2. This model is validated by two sets of field data. Finally, parametric study is conducted to explore key parameters which affect the short-term and long-term gas productions. It is found that the two-phase flowback and the flow consistency between matrix and fracture network have significant influences on cumulative gas production. The multiscale diffusion mechanisms in different zones should be carefully considered in the flowback model.

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Section: Introductionmentioning

confidence: 99%

“…The immediate two-phase flow after the shut-in period was observed in the Barnett shale and the Marcellus shale [16]. A transient flowing model considering the effect of twophase flow after the hydraulic fracturing was also developed for gas production [13]. This model further analyzes the response of transient pressure.…”

Section: Introductionmentioning

confidence: 99%

A Two-Phase Flowback Model for Multiscale Diffusion and Flow in Fractured Shale Gas Reservoirs

Wang

Gao

et al. 2018

Geofluids

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“…These linear models are simple and practical to identify the linear flow regime, but ignore the fracture interferences. To overcome the shortcomings of linear models, some works (Zhao et al, 2013(Zhao et al, , 2014Zhang et al, 2015a) derived semi-analytical models by using point source function to study the rate decline for MFHW, but different factors were ignored in their models, such as stimulated reservoirs volume (SRV) (Zhao et al, 2013;Xie et al, 2015), and adsorption/desorption (Zhao et al, 2014). Later, Su et al (2015) developed a compositional dual-porosity model that took multiple mechanisms and SRV into consideration to analyze pressure performance of MFHW, but the production decline behaviors were not discussed in their work.…”

Section: Introductionmentioning

confidence: 99%

Blasingame decline type curves with material balance pseudo-time modified for multi-fractured horizontal wells in shale gas reservoirs

Wei

Duan

Dong

et al. 2016

Journal of Natural Gas Science and Engineering

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Rate-Transient Analysis in Multifractured Horizontal Wells of Tight Oil Reservoir

Luo

Zhang

et al. 2018

SPE Production &Amp; Operations

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Summary Multifractured horizontal wells (MFHWs) have become the most commonly used technology for developing unconventional oil and gas reservoirs. Because unconventional reservoirs are currently the focus of exploration and exploitation around the world, a growing number of researchers and scholars are concentrating on production-performance evaluation of unconventional MFHWs to obtain the stimulated reservoir volume (SRV) or hydraulic-fracture properties, which are usually obtained from expensive reservoir tests or production logs. Rate-transient-analysis (RTA) techniques that use continuous-production and flowing-pressure data have proved to be convenient and applicable approaches to estimate the reservoir parameters and hydraulic-fracture properties. Although many cases or work flows of RTA have been previously studied, most of those works were performed for shale-gas or conventional reservoirs. Few studies on RTA have been conducted for MFHWs completed in tight oil reservoirs, particularly for actual field cases in which the usually scattered production data significantly increase the difficulty in analyzing the production performance. In this research, the authors focus on using convenient and economical methods (RTA techniques) to obtain the SRV parameters and hydraulic-fracture properties that characterize the fracturing-treatment effectiveness of an actual MFHW in a tight oil reservoir, which many engineers and technical personnel expect to achieve. A comprehensive work flow [including production-data filtering, flow-regime diagnosis, straight-line analysis, type-curve matching (TCM), analytical-model analysis (AMA), numerical-model analysis (NMA), and uncertainty and nonuniqueness analysis] has been developed to perform a production-performance analysis of an MFHW completed in a tight oil reservoir. In particular, two approaches for calculating the permeability of SRV (kSRV) and effective half-length of hydraulic fracture (Xf) have been introduced. Moreover, the dual permeability parameters, the storativity ratio, and the interporosity coefficient (ω and λ, respectively), have been derived to enter into the AMA model to improve the accuracy of history matching. With the combination of AMA and NMA, the estimated ultimate recovery (EUR) of an actual MFHW completed in a tight oil reservoir can be predicted. Considering the uncertainty and nonuniqueness of the original reservoir parameters or nature of the adopted methods, a probabilistic analysis using Monte Carlo simulation has been performed to address the uncertainty of the analysis results. In addition, a simplified application of the developed method has been introduced. To demonstrate the feasibility and practicability of the developed work flow, two field cases from an actual tight oil reservoir have been analyzed. The consistent analysis results for field cases validate the developed work flow and proposed methods.

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Production Decline Analysis for Two-Phase Flow in Multifractured Horizontal Well in Shale Gas Reservoirs

Cited by 4 publications

References 31 publications

A Two-Phase Flowback Model for Multiscale Diffusion and Flow in Fractured Shale Gas Reservoirs

A Two-Phase Flowback Model for Multiscale Diffusion and Flow in Fractured Shale Gas Reservoirs

Blasingame decline type curves with material balance pseudo-time modified for multi-fractured horizontal wells in shale gas reservoirs

Rate-Transient Analysis in Multifractured Horizontal Wells of Tight Oil Reservoir

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