Production Analysis of Linear Flow Into Fractured Tight Gas Wells

Wattenbarger, R.A.; El-Banbi, Ahmed; Villegas, Mauricio; Maggard, James Bryan

doi:10.2118/39931-ms

Cited by 361 publications

(118 citation statements)

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“…These methods include Wattenbarger et al (1998), Wattenbarger (2005, 2006), Clarkson (2011a, 2011b), Clarkson et al (2011) and Nobakht et al (2011). A number of numericallysimulated cases were generated for constant flowing pressure production to compare the fracture half-lengths calculated from the above-mentioned methods, except Nobakht and Clarkson (2011a) as it is developed for analyzing constant rate production.…”

Section: Discussionmentioning

confidence: 99%

Analysis of production data in shale gas reservoirs: Rigorous corrections for fluid and flow properties

Nobakht¹,

Clarkson²

2012

Journal of Natural Gas Science and Engineering

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Section: Discussionmentioning

confidence: 99%

Analysis of production data in shale gas reservoirs: Rigorous corrections for fluid and flow properties

Nobakht¹,

Clarkson²

2012

Journal of Natural Gas Science and Engineering

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“…Theoretical basis for flow regime identification Wattenbarger et al (1998) presented an application of the solution to the one-dimensional diffusivity (linear coordinates) equation for a closed rectangular boundary to facilitate analysis of production data in tight gas wells. The solution shows that for the constant pressure inner boundary condition, a log-log plot of rate versus time plots as a straight line with a slope of one-half at early times and as an exponential curve at late times.…”

Section: Methodsmentioning

confidence: 99%

An approach to modeling production decline in unconventional reservoirs

Ogunyomi

Dong

et al. 2017

J Petrol Explor Prod Technol

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Most decline curve methods have two main limitations; the model parameters as a rule are not functions of reservoir parameters and may yield unrealistic (nonphysical) values of expected ultimate recovery (EUR) because boundary-dominated flow may not develop in unconventional reservoirs. Over the past few years, several empirical models have emerged to address the second limitation, but they are challenged by the time to transition from infinite-acting flow period to the boundary-dominated flow. In this study, we performed statistical and modelbased analysis of production data from hydraulically fractured horizontal oil wells and present a method to mitigate some of the limitations highlighted above. The production data were carefully analyzed to identify the flow regimes and understand the overall decline behavior. Following this step, we performed model-based analysis using the parallel flow model (sum of exponential terms), and the logistic growth model. After the model-based analysis, the model parameters were analyzed statistically and cross-plotted against available reservoir and well completion parameters. Based on the conclusion from the cross-plots and statistical analysis, we used design of experiments (DoE) and numerical reservoir simulations to develop functions that relate the model parameters and reservoir/well completion properties. Results from this work indicate that the production characteristics from these wells are highly variable. In addition, the parallel flow model indicates that there are at least two to three different time domains in the production behavior and that they are not the result of operational changes, such as well shut-in or operating pressure changes at the surface. All the models used in this study provide very good fits to the data, and all provide realistic estimates of EUR. The cross-plots of model parameters and some reservoir/well completion properties indicate that there is some relationship between them, which we developed using DoE and flow simulations. We have also shown how these models can be applied to obtain realistic estimates of EUR from early-time production data in unconventional oil reservoirs.

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“…Apparently, the behaviors of the pseudo-time factor over time depend on the correlated fluid properties and depletion patterns in the system. A full discussion of the production performances for these cases under study is presented using the production decline model of one-dimensional flow [25].Consider a vertical well intercepted by a uniform flux vertical fracture in the center of a homogeneous rectangular reservoir, as shown in Figure 1.The height, length, and width are h, x e , and y e , respectively. The half-length of the fracture is y f , and the length of the fracture is equal to the width of the reservoir.…”

Section: Behaviors Of the Pseudo-time Factormentioning

confidence: 99%

“…In some cases, the adoption of the composite flow model can replace the application of a two-dimensional or three-dimensional flow model when analyzing the transient performance of a fractured well. In terms of the analysis on a composite flow model, Wattenbarger et al, claimed that the flow near production wells in tight gas reservoirs is dominated by a one-dimensional flow after hydraulic fracturing treatment, and they reported a rate decline analysis of gas wells using a one-dimensional flow model [25]. Cinco et al, performed an appropriate analysis of fractured wells according to the bilinear flow theory for the early-time pressure behavior [26].…”

Section: Introductionmentioning

confidence: 99%

Rate Decline Analysis of Vertically Fractured Wells in Shale Gas Reservoirs

et al. 2017

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Based on the porous flow theory, an extension of the pseudo-functions approach for the solution of non-linear partial differential equations considering adsorption-desorption effects was used to investigate the transient flow behavior of fractured wells in shale gas reservoirs. The pseudo-time factor was employed to effectively linearize the partial differential equations of the unsteady flow response. The production performance of vertically fractured wells in shale gas reservoirs under either constant flow rate or constant bottom-hole pressure conditions was analyzed using the composite flow model. The calculation results indicate that the non-linearities that develop in the gas diffusivity equation have significant effects on the unsteady response, leading to a larger pressure depletion and rate decline in the late-time period. In addition, gas desorption from the shale acts as a recharge source, which relieves the gas production rate of decline. Greater values for the Langmuir volumes or Langmuir pressures provide additional pressure support, leading to a lower rate decline while the flowing well bottom-hole pressure is maintained. The reservoir size mainly affects the duration of the pressure depletion and rate decline. In the case of ignoring the non-linearity and adsorption-desorption effect in the differential equation, a greater rate decline under constant bottom-hole pressure production can be obtained during the boundary-dominated depletion. This work provides a better understanding of gas desorption in shale gas reservoirs and new insight into investigating the production performances of fractured gas well.

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Production Analysis of Linear Flow Into Fractured Tight Gas Wells

Cited by 361 publications

References 0 publications

Analysis of production data in shale gas reservoirs: Rigorous corrections for fluid and flow properties

Analysis of production data in shale gas reservoirs: Rigorous corrections for fluid and flow properties

An approach to modeling production decline in unconventional reservoirs

Rate Decline Analysis of Vertically Fractured Wells in Shale Gas Reservoirs

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