Simulation of hydraulically fractured horizontal and vertical wells to well testing accuracy using unstructured grids

Banerjee, Rangan; Gunasekera, D.; Fletcher, K.M.U.

doi:10.3997/2214-4609.201406124

Cited by 5 publications

(2 citation statements)

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“…[37] We will consider in the present work both simple deterministic test configurations and more realistic and complex randomly fractured porous media. Whereas specific discretization techniques could be used in the first situations, for instance, with local grid refinements [see, e.g., Banerjee et al, 2000], we are really interested in the latter case where geometrical randomness requires great flexibility.…”

Section: Numerical Modelmentioning

confidence: 99%

Pressure drawdown well tests in fractured porous media

Bogdanov

Mourzenko²,

Thovert³

et al. 2003

Water Resources Research

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[1] A general three-dimensional numerical model for single-phase, slightly compressible flow through fractured porous media is introduced. It is based on a discrete fracture representation. Applications to the simulation of pressure drawdown well tests are presented, for complex situations where the well intercepts a random fracture network with various fracture densities and conductivities. The well pressure response can be modeled as a function of its interconnectivity with the fracture network.

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Section: Numerical Modelmentioning

confidence: 99%

Pressure drawdown well tests in fractured porous media

Bogdanov

Mourzenko²,

Thovert³

et al. 2003

Water Resources Research

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“…14 In the first example, we consider a vertical fracture that intersects with the open interval in the middle of a 20-ft-thick formation, where the porosity, φ, is 0.2, horizontal, k h, and vertical, k v, permeabilities are 10 md, fluid viscosity, µ, is 1 cp, total compressibility, c t, is 1.5E-6 1/psi, fracture porosity is 0.01, and fracture length is 14 ft. As shown in Fig. A commercial well test simulator 13,14 that automatically generates a simulation model and runs a reservoir simulator has been used to generate fractures and to conduct the simulation.…”

Section: Fracture Conductivitiy Determination-synthetic Examplesmentioning

confidence: 99%

Fault and Fracture Characterization Using 3D Interval Pressure Transient Tests

Zeybek

Kuchuk

Hafez

2002

Proceedings of Abu Dhabi International Petroleum Exhibition and Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractPermeability is one of the most important parameters that affects almost all phases of reservoir management and well performance. It is considered to be the most basic formation property and a tensor (directional dependence). As stated well by Weber 1 in 1986: "Reservoir heterogeneity is among the major reasons why enhanced oil recovery is so difficult. Projects undertaken without detail reservoir evaluation often end in failures related to unexpected baffles to flow, permeability heterogeneity, or wrong appreciation of the residual oil distribution." Fractures and faults can behave as barriers, baffles, or open channels to fluid flow in the reservoir and often cause early water breakthrough, gas channeling, etc. that are costly.In this paper, we use 3D interval pressure transient tests to estimate horizontal and vertical permeabilities and to delineate of fracture and fault conductivities. 3D interval pressure transient tests are conducted using the wireline conveyed dualinflatable-packer module with multiple observation probes that can be set along the wellbore a number of times as the number of fracture and fault zones require. The dual-packer, with one meter open interval is set against the borehole wall to hydraulically isolate the tested section from the rest of the wellbore. In this set up, the dual-packer open interval encircles fractured and/or faulted zones. The formation fluid is produced through the isolated packer interval for more than a few hours, after which a pressure buildup test takes place. For the interval tests, the observation probes are usually mounted above and/or below the packer module. These probes measure pressure changes due production from the open interval at different locations in the formation .

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Seismic-to-Simulation for Unconventional Reservoir Development

et al. 2011

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The completion strategy and hydraulic fracture stimulation are the keys to economic success in unconventional reservoirs. Therefore, reservoir engineering workflows in unconventional reservoirs need to focus on completion and stimulation optimization as much as they do well placement and spacing. This well-level focus requires the integration of hydraulic fracture modeling software and the ability to utilize measurements specific to unconventional reservoirs. This paper details a comprehensive integration of software, data, and specialized measurements specific to unconventional reservoirs that allows efficient full-cycle seismic-to-simulation evaluations.It is very important to properly model hydraulic fracture propagation and hydrocarbon production mechanisms in unconventional reservoirs, a significant departure from conventional reservoir simulation workflows. Seismic-to-simulation workflows in unconventional reservoirs require hydraulic fracture models that properly simulate complex fracture propagation which is common in many unconventional reservoirs, algorithms to automatically develop discrete reservoir simulation grids to rigorously model the hydrocarbon production from complex hydraulic fractures, and the ability to efficiently integrate microseismic measurements with geological and geophysical data. The introduction of complex hydraulic fracture propagation models now allows these work-flows to be implemented. This paper documents an efficient, yet rigorous, integration of geological and geophysical data with complex fracture models, single-well completion and stimulation focused reservoir simulation, and microseismic measurements. The implementation of a common software platform and the development of specialized gridding algorithms allow complex hydraulic fracture models to be calibrated using microseismic measurements in the context of local geology and structure. The complex hydraulic fracture geometry, including the distribution of proppant, is automatically gridded to a common Earth Model for single-well reservoir simulation. The software platform, newly developed complex hydraulic fracture models, and automated gridding algorithms are illustrated in a case history from the Barnett Shale unconventional gas play.

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Simulation of hydraulically fractured horizontal and vertical wells to well testing accuracy using unstructured grids

Cited by 5 publications

References 0 publications

Pressure drawdown well tests in fractured porous media

Pressure drawdown well tests in fractured porous media

Fault and Fracture Characterization Using 3D Interval Pressure Transient Tests

Seismic-to-Simulation for Unconventional Reservoir Development

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