Injection/Fall-off Testing in the Marcellus Shale: Using Reservoir Knowledge to Improve Operational Efficiency

Yeager, Bryce B.; Meyer, Bruce R.

doi:10.2118/139067-ms

Cited by 25 publications

(16 citation statements)

References 14 publications

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“…In general, flowing bottom hole pressure and gas production data of shale wells are used to perform history matching to validate the reservoir model. The field production data of a Marcellus shale well is chosen to perform history matching, and the well was located between the lower section and upper section of the Marcellus formation with a true vertical depth ranging from 8054 ft to 8066 ft [32]. In the field case study, the horizontal well was stimulated with seven hydraulic fracturing stages, and each stage has four active clusters with cluster spacing of 50 ft.…”

Section: Validation Of Numerical Modelmentioning

confidence: 99%

“…The flowing bottom hole pressure is calculated based on the measured surface tubing pressure by considering the gas and water flow rates, as shown in Fig. 2 [32]. It decreases from 1600 psi initially to about 400 psi in a nine-month production period.…”

Section: Validation Of Numerical Modelmentioning

confidence: 99%

“…It decreases from 1600 psi initially to about 400 psi in a nine-month production period. The inner diameter of wellbore is 0.7292 ft, and more details about the well can be found in the work by Yeager and Meyer [32]. The bottom hole pressure is an input in the reservoir simulator as a history-matching constraint, and cumulative gas production is a history-matching variable.…”

Section: Validation Of Numerical Modelmentioning

confidence: 99%

“…The bottom hole pressure is an input in the reservoir simulator as a history-matching constraint, and cumulative gas production is a history-matching variable. In addition, matrix permeability, fracture half-length and fracture conductivity are tuned manually to perform history matching and the other parameters are kept constant, which are based on the work by Yeager and Meyer [32]. Langmuir pressure of 500 psi, Langmuir volume of 200 scf/ton, and shale density of 2.46 g/cm 3 [26] are used in the gas desorption model.…”

Section: Validation Of Numerical Modelmentioning

confidence: 99%

See 3 more Smart Citations

Numerical study of the effect of uneven proppant distribution between multiple fractures on shale gas well performance

Zhang

et al. 2015

Fuel

106

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Section: Validation Of Numerical Modelmentioning

confidence: 99%

Section: Validation Of Numerical Modelmentioning

confidence: 99%

Section: Validation Of Numerical Modelmentioning

confidence: 99%

Section: Validation Of Numerical Modelmentioning

confidence: 99%

See 2 more Smart Citations

Numerical study of the effect of uneven proppant distribution between multiple fractures on shale gas well performance

Zhang

et al. 2015

Fuel

106

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“…The flowing bottomhole pressure and gas production rate are reproduced from Yeager and Meyer (2010). Due to variable pressure/rate and noise of field data, corrections are necessary before analysis is performed.…”

Section: Field Examplementioning

confidence: 99%

Application of type curves for pressure transient analysis of multiple fractured horizontal wells in shale gas reservoirs

Kim

Park

Lee

2016

IJOGCT

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Pressure transient analysis for shale gas reservoirs requires comprehensive understanding related to nonlinear gas flow process as well as hydraulic fracture properties. A major purpose of this study is to demonstrate how this issue is addressed by pressure transient analysis for multiple fractured horizontal wells in shale gas reservoirs. Extensive numerical simulations were conducted to model transient pressure behaviour of a fractured horizontal well and the results were applied to well test analysis in shale gas reservoirs. This paper presents a comprehensive reservoir simulation model to investigate the characteristics of pressure transient responses under the influences of hydraulic fracture properties and nonlinear gas flow mechanism. The numerical simulations provided various type curves for transient pressure responses in fractured horizontal production wells. Results from type-curve matching for synthetic pressure data demonstrate that the conventional analysis approach may still be applicable for analysis of shale gas reservoirs.

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Optimization of the shale gas reservoir fracture parameters based on the fully coupled gas flow and effective stress model

Wang

Zeng³

et al. 2021

Energy Science & Engineering

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Unconventional reservoirs are characterized by low permeability, low porosity, and tight structure, which bring great difficulties in gas and oil production. Multistage hydraulic fracturing and horizontal drilling technology have been used to solve these problems successfully. [1][2][3] Drilling horizontal wells on shale reservoirs causes hydraulic fractures and many secondary fractures, forming fracturing effect zones, as shown in Figure 1, which consist of the horizontal wells with

show abstract

Injection/Fall-off Testing in the Marcellus Shale: Using Reservoir Knowledge to Improve Operational Efficiency

Cited by 25 publications

References 14 publications

Numerical study of the effect of uneven proppant distribution between multiple fractures on shale gas well performance

Numerical study of the effect of uneven proppant distribution between multiple fractures on shale gas well performance

Application of type curves for pressure transient analysis of multiple fractured horizontal wells in shale gas reservoirs

Optimization of the shale gas reservoir fracture parameters based on the fully coupled gas flow and effective stress model

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