A Semianalytical, Pressure-Transient Model for Horizontal and Multilateral Wells in Composite, Layered, and Compartmentalized Reservoirs

Medeiros, Flavio; Özkan, Erdal; Kazemi, Hossein

doi:10.2118/102834-ms

Cited by 30 publications

(23 citation statements)

References 9 publications

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“…More accurate semi-analytical models for single vertical fractures were developed later (e.g., Blasingame and Poe Jr., 1993). Prior to the development of models for multiply-fractured horizontal wells (Medeiros et al, 2006), it was common practice to represent these multiple fractures with an equivalent single fracture. More recently, several other analytical and semi-analytical models have been developed (Bello and Wattenbarger, 2008;Mattar, 2008;Anderson et al, 2010), but these, despite their speed, cannot accurately handle the very highly nonlinear aspects of shale-gas and tightgas reservoirs, cannot describe complex domain geometries, and cannot accurately capture gas sorption and desorption from the matrix (a non-linear process that does not lend itself to analytical solutions), multiphase flow, unconsolidation, and several nonideal and complex fracture networks (Houze et al, 2010).…”

Section: Tcf In 2009 (Us Doe 2009) In Its Annual Energy Outlook Formentioning

confidence: 99%

The RealGas and RealGasH2O options of the TOUGH+ code for the simulation of coupled fluid and heat flow in tight/shale gas systems

Moridis

Freeman

2014

Computers & Geosciences

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We developed two new EOS additions to the TOUGH+ family of codes, the RealGasH2O and RealGas. The RealGasH2O EOS option describes the nonisothermal two-phase flow of water and a real gas mixture in gas reservoirs, with a particular focus in ultra-tight (such as tight-sand and shale gas) reservoirs. The gas mixture is treated as either a single-pseudo-component having a fixed composition, or as a multicomponent system composed of up to 9 individual real gases. The RealGas option has the same general capabilities, but does not include water, thus describing a single-phase, dry-gas system. In addition to the standard capabilities of all members of the TOUGH+ family of codes (fully-implicit, compositional simulators using both structured and unstructured grids), the capabilities of the two codes include: coupled flow and thermal effects in porous and/or fractured media, real gas behavior, inertial Their capabilities are demonstrated in a series of problems of increasing complexity, ranging from isothermal flow in simpler 1D and 2D conventional gas reservoirs, to nonisothermal gas flow in 3D fractured shale gas reservoirs involving 4 types of fractures, micro-flow, non-Darcy flow and gas composition changes during production.

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Section: Tcf In 2009 (Us Doe 2009) In Its Annual Energy Outlook Formentioning

confidence: 99%

The RealGas and RealGasH2O options of the TOUGH+ code for the simulation of coupled fluid and heat flow in tight/shale gas systems

Moridis

Freeman

2014

Computers & Geosciences

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“…For each block, the solution is constructed from Green's formula and discretized at the block and source (well) boundaries (Gringarten and Ramey, 1974, Ozkan and Raghavan, 1991a, 1991b. The overall pressure response of the system is obtained by considering the flux and pressure continuity at the interfaces between contiguous blocks and the material balance on sources (Medeiros et al, 2006).…”

Section: Semi-analytical Modelmentioning

confidence: 99%

“…The results presented in this work are based on a semianalytical model developed by Medeiros et al (2006). The model was derived from the Green's function formulation of the solution for the diffusivity equation (Gringarten and Ramey, 1974, Ozkan and Raghavan, 1991a, 1991b and has the capability to incorporate local heterogeneities.…”

Section: Introductionmentioning

confidence: 99%

Productivity and Drainage Area of Fractured Horizontal Wells in Tight Gas Reservoirs

2007

Self Cite

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper discusses the performance and productivity of fractured horizontal wells in heterogeneous, tight-gas formations. Production characteristics and flow regimes of unfractured and fractured horizontal wells are documented. The results show that if hydraulic fracturing affects stress distribution to create or rejuvenate natural fractures around the well, productivity of the system is significantly increased. Unless there is significant contrast between the conductivities of the hydraulic and natural fractures, hydraulic fractures may not significantly contribute to the productivity. For extremely tight formations, effective drainage area may be limited to the naturally fractured region around the well and the hydraulic fractures. It is also shown that very long transient flow periods govern the productivity and economics of fractured horizontal wells in tight formations. The results of this study are also applicable to oil production from fractured shale. case D J J J J J = =( 1 4 )

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“…Raghavan et al [1997] provided a mathematical description of inflow into the late-time compound-linear flow regime. Medeiros et al [2006] introduced a semi-analytical solution which models the entire range of flow regimes surrounding a multiply-fractured horizontal well system. They extended the idea beyond the assumption of planar hydraulic fractures to include a dual permeability region near the fracture faces to represent a complex-fractured region surrounding the primary hydraulic fracture.…”

Section: Introductionmentioning

confidence: 99%

A Numerical Study of Performance for Tight Gas and Shale Gas Reservoir Systems

et al. 2009

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Various analytical, semi-analytical, and empirical models have been proposed to characterize rate/pressure behavior as a function of time in tight/shale gas systems featuring a horizontal well with multiple hydraulic fractures. Despite a few analytical models as well as a small number of published numerical studies there is currently little consensus regarding the large-scale flow behavior over time in such systems, particularly regarding the dominant flow regimes and whether or not reservoir properties/volume can be estimated from well performance data.We constructed a fit-for-purpose numerical simulator which accounts for a variety of production features pertinent to these systems -specifically: ultra-tight matrix permeability, hydraulically fractured horizontal wells, multiple porosity and permeability fields, and desorption. These features cover the production mechanisms which are currently believed to be relevant in tight/shale gas systems.We employ the numerical simulator to examine various tight/shale gas systems and to identify/illustrate the various flow regimes which progressively occur over time. We visualize the flow regimes using both specialized plots of rate and pressure functions, as well as maps of pressure distributions.We use pressure maps to demonstrate the various flow regimes and their transitions in tight gas systems. In a typical tight gas system, we illustrate the initial linear flow into the hydraulic fractures (i.e., formation linear flow), transitioning to compound formation linear flow, and eventually transforming into elliptical flow.We explore variations of possible shale gas system models. Based on diffusive flow (with/without desorption), we show that due to the extremely low permeability of shale, the flow behavior is dominated by the extent of and configuration of the fractures.This work expands our understanding of flow behavior in tight gas and shale gas systems, where such an understanding may ultimately be used to estimate reservoir properties and reserves in these types of reservoirs.

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A Semianalytical, Pressure-Transient Model for Horizontal and Multilateral Wells in Composite, Layered, and Compartmentalized Reservoirs

Cited by 30 publications

References 9 publications

The RealGas and RealGasH2O options of the TOUGH+ code for the simulation of coupled fluid and heat flow in tight/shale gas systems

The RealGas and RealGasH2O options of the TOUGH+ code for the simulation of coupled fluid and heat flow in tight/shale gas systems

Productivity and Drainage Area of Fractured Horizontal Wells in Tight Gas Reservoirs

A Numerical Study of Performance for Tight Gas and Shale Gas Reservoir Systems

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