New Methods to Predict Inflow Performance of Multiply Fractured Horizontal Wells under Two-Phase Condition and Optimize Number of Fracture Stages

Zhang, He; Han, Guoqing; Houeto, Okounola Ernst Fabien; Lessard, R. W.; Wang, Wenhao; Li, Jun

doi:10.2118/152837-ms

Cited by 7 publications

(1 citation statement)

References 27 publications

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“…These include use of dual-porosity models, enhancement of the productivity index of the fractured wells (Zhang et al 2012), virtual well perforations to simulate the fractures (Bogachev et al 2011), and explicit fine-scale gridding. In full-field simulations, where an entire reservoir with complex geometry, multiple wells, and possibly faults is modeled, local grid refinement (LGR) is a popular methodology to represent hydraulic fractures.…”

Section: Introductionmentioning

confidence: 99%

Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models

et al. 2013

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Hydraulic fracturing is a stimulation treatment routinely performed on oil and gas wells in low-permeability reservoirs. However, simulating fractured wells is still challenging and impractical using local grid refinement in full-field models with a large number of wells each with multiple fractures. This paper describes a novel modeling technique by which hydraulic fractures are represented as part of the well model, rather than any form of refinement in the simulation grid. In this approach a planar fracture is modeled by the mesh formed from the interconnected branches of a multilateral, multisegment well. The main advantages are: 1) the fracture mesh is made independent of the simulation grid and thus model building is simpler; 2) fractures can be added and altered at any simulation time; 3) fractures can intersect the reservoir grid lines at any angle; 4) fracture geometry and properties can be fully honored. This technique is designed to model long-term pseudo-steady state fracture flows and uses Darcy flow equations in the lateral well branches that represent the fracture.The accuracy, stability, and practicality of this new technique have been investigated using a suite of simulation models ranging from a single well in a homogeneous reservoir to a real field sector model with numerous wells, each with multiple fractures. Where possible, the behavior of a reference model-built using traditional grid-refinement techniques-is compared against the multilateral, multisegment well model equivalent. The results of these experiments presented in this paper show a close agreement between the reference gridded fractures and the well model fractures when the system reaches a pseudosteady state. They also show that the new approach suffers from a lesser degree of numerical instability when modeling extremely thin and highly conductive fractures. Finally, the results confirm the practicality and flexibility of this approach. IntroductionThe use of hydraulic fracturing for well stimulation is widespread in the industry. This treatment is particularly prevalent in oil shales and gas shales and tight formations in general, where virtually all production can be attributed to the practice of fracturing. It is also used in the context of tight oil reservoirs; for example, in deepwater scenarios where the costs of drilling and completion are very high and well productivity, which is dictated by hydraulic fractures, is vital.Hydraulic fracturing can dramatically change the flow dynamics of a reservoir, so its correct modeling in reservoir simulation can be critical. However, the presence of hydraulic fractures presents a challenge in flow simulation. This is because these fractures introduce effects that operate on different length and time scales than usual reservoir dynamics.To overcome this problem, a multitude of modeling techniques and workarounds has been developed. These include use of dual-porosity models, enhancement of the productivity index of the fractured wells (Zhang et al. 2012), virtual well perforations to s...

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Section: Introductionmentioning

confidence: 99%

Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models

et al. 2013

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Predicting productivity index of hydraulically fractured formations

Al-Rbeawi

Tiab

2013

Journal of Petroleum Science and Engineering

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Optimization of Horizontal Well Design to Maximize Recoverable Hydrocarbon

et al. 2012

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In the boom of unconventional resource exploration, horizontal completion has been widely used. Horizontal well has the advantages of increasing productivity index, preventing gas or water coning, avoiding sanding out, enhancing drainage area, reducing drilling pad and footprint, and accelerating recovery. Although these advantages have been well recognized over vertical completion, the quantitative contribution is not yet to be investigated. The current design of horizontal well is primarily derived from field experience. This consists of more or less arbitrary contents. To fill this gap, this paper presents a model to incorporate production from different lengths of horizontal well, cost of the drilling and completion, discount of revenue, and cost by different timing. The achieved optimum horizontal well design leads to a maximized net present value (NPV) for operators.

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New Methods to Predict Inflow Performance of Multiply Fractured Horizontal Wells under Two-Phase Condition and Optimize Number of Fracture Stages

Cited by 7 publications

References 27 publications

Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models

Representing Hydraulic Fractures Using a Multilateral, Multisegment Well in Simulation Models

Predicting productivity index of hydraulically fractured formations

Optimization of Horizontal Well Design to Maximize Recoverable Hydrocarbon

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