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Jamiolahmady, Mahmoud; Danesh, Ali; Tehrani, D.H.; Duncan, Dugald B.

doi:10.1023/a:1006645515791

Cited by 63 publications

(33 citation statements)

References 22 publications

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“…The presence of liquid hydrocarbon and water in the vicinity of wellbores was considered as the main restricting parameter making only 10% of original gas in place recoverable from this reservoir (Engineer 1985). A large number of theoretical and experimental studies have been devoted to understanding, modeling, and predicting the condensate accumulation and its associated impaired well productivity (O'Dell and Miller 1967;Fussell 1973;Danesh et al 1991;Henderson et al 1993Henderson et al , 1998Fevang and Whitson 1996;Mott 2002;Jamiolahmady et al 2003).…”

Section: Introductionmentioning

confidence: 99%

“…At such conditions, the gas passage is intermittently blocked when the condensate evolves in the pore throats and subsequently reopens when continuous viscous flow of gas breaks the capillary barrier. As a result, the increase of relative permeability with increasing velocity has been reported for gas/condensate systems at low-interfacial-tension conditions, which is known as positive coupling (Henderson et al 2000;Jamiolahmady et al 2000Jamiolahmady et al , 2003. These two distinct features pertaining to condensing fluids (i.e., coupling and inertia) can only be captured through demanding and expensive steady-state relative permeability measurements by use of gas/condensate fluids (Jamiolahmady et al 2009).…”

Section: Introductionmentioning

confidence: 99%

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Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Fahimpour¹,

Jamiolahmady²

2015

SPE Journal

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Significant reduction in well productivity of gas/condensate reservoirs occurs because of reduced gas mobility caused by the presence of condensate/water liquid phases around the wellbore.There are certain fluorinated wettability modifiers that are capable of delivering a good level of oil and water repellency to the rock surface, making it intermediate gas-wet and alleviating such liquid blockages. The main objective of this experimental work has been to evaluate the performance of such chemicals for wettability alteration of carbonate rocks, which have received much less attention in comparison with sandstone rocks. Screening tests, including contact-angle measurements, unsteady-state-flow tests, and compatibility tests with brine, were performed by use of mainly anionic and nonionic fluorosurfactants.Results demonstrated that on positively charged carbonate surfaces, the anionic chemicals were sufficiently effective to repel the liquid phase, whereas the nonionic chemicals showed an excellent stability in brine media. A new approach of combining anionic and nonionic chemical agents was proposed to benefit from these two positive features of an integrated chemical solution. A number of low-and high-permeability carbonate-core samples were successfully treated by use of chemicals selected through screening tests. Optimization of the solution composition and its filtration before injecting it into the core proved very effective in reducing/eliminating the risk of possible permeability damage because of deposition of large chemical aggregates on the rock surface. The chemical solution optimized in this study can be considered as a potential wettability modifier for mitigating the negative impact of condensate/water banking in gas/condensate carbonate reservoirs.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Fahimpour¹,

Jamiolahmady²

2015

SPE Journal

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“…This behavior results in an improvement of relative permeability caused by an increase in velocity. This flow behavior is a well-established phenomenon proven both experimentally (Danesh et al 1994;Henderson et al 1995;Blom et al 1997;Ali et al 1997) and theoretically (Jamiolahmady et al 2001(Jamiolahmady et al , 2003. It is referred to as the "positive coupling" and has been shown to be in strong competition with the negative inertia at very high velocities (Henderson et al 2001).…”

Section: Introductionmentioning

confidence: 76%

Gas-Condensate Flow in Perforated Regions

Jamiolahmady¹,

Danesh²,

Sohrabi³

et al. 2007

SPE Journal

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The most crucial region with regard to affecting well productivity is the perforated region. Considerable effort has been directed to study this subject mathematically by many investigators, but they have been mainly focused on single-phase flow, while two-phase flow has received less attention.It has been demonstrated, first by Danesh et al. (1994) and subsequently by other researchers (Henderson et al. 1995;Blom et al. 1997;Ali et al. 1997), that the gas and condensate relative permeability (k r ) can increase significantly by increasing the flow rate, contrary to the common understanding. This effect, known as positive coupling, complicates the flow of gas and condensate near the wellbore even further when it competes with the inertial forces at higher velocities typical of those around perforation tips.The flow of gas and condensate in the perforated region was studied in this work using a finite-element modeling approach. The model allows for changes in fluid properties and accounts for the positive coupling and negative inertial effects using a fractionalflow-based relative-permeability correlation. A sensitivity analysis on the impact of perforation characteristics such as density, phasing, length, and radius as well as that of fluid properties, rock characteristics, wellbore radius, fractional flow, and rate on well productivity was conducted, resulting in some valuable practical guidelines for optimum perforation design.

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“…This representation is then used to model flow by computing and tracking the pore-scale configuration of fluid phases for different displacement sequences using empirical equations derived normally from semianalytical expressions for pores of a simple geometry. This approach has proved successful for the study of various phenomena, such as interfacial area and capillary pressure [12][13][14], reaction [15,16], drying [17], evaporation [18], dissolution [19,20], electrical properties [21][22][23][24], non-Newtonian flow [25,26], foam flow [27], solution gas drives [28,29], gas condensate systems [30][31][32], water vapor transport [33], dispersion [34][35][36], and two-and three-phase flow [37][38][39][40][41][42]. However, for pore-network models to have any predictive power for studying flow through the full range of samples encountered in geological settings, an accurate parametrization of the void space is needed.…”

Section: Introductionmentioning

confidence: 99%

Generalized network modeling: Network extraction as a coarse-scale discretization of the void space of porous media

2017

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A generalized network extraction workflow is developed for parameterizing three-dimensional (3D) images of porous media. The aim of this workflow is to reduce the uncertainties in conventional network modeling predictions introduced due to the oversimplification of complex pore geometries encountered in natural porous media. The generalized network serves as a coarse discretization of the surface generated from a medial-axis transformation of the 3D image. This discretization divides the void space into individual pores and then subdivides each pore into sub-elements called half-throat connections. Each half-throat connection is further segmented into corners by analyzing the medial axis curves of its axial plane. The parameters approximating each corner-corner angle, volume, and conductivity-are extracted at different discretization levels, corresponding to different wetting layer thickness and local capillary pressures during multiphase flow simulations. Conductivities are calculated using direct single-phase flow simulation so that the network can reproduce the single-phase flow permeability of the underlying image exactly. We first validate the algorithm by using it to discretize synthetic angular pore geometries and show that the network model reproduces the corner angles accurately. We then extract network models from micro-CT images of porous rocks and show that the network extraction preserves macroscopic properties, the permeability and formation factor, and the statistics of the micro-CT images.

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Cited by 63 publications

References 22 publications

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Gas-Condensate Flow in Perforated Regions

Generalized network modeling: Network extraction as a coarse-scale discretization of the void space of porous media

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