on simulation of flow in tight and shale gas reservoirs pdf Thursday, May 6, 2021 5:36:39 PM

On Simulation Of Flow In Tight And Shale Gas Reservoirs Pdf

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Development of unconventional shale gas reservoirs SGRs has been boosted by the advancements in two key technologies: horizontal drilling and multi-stage hydraulic fracturing. A large number of multi-stage fractured horizontal wells MsFHW have been drilled to enhance reservoir production performance.

Shale Gas and Tight Oil Reservoir Simulation delivers the latest research and applications used to better manage and interpret simulating production from shale gas and tight oil reservoirs. Starting with basic fundamentals, the book then includes real field data that will not only generate reliable reserve estimation, but also predict the effective range of reservoir and fracture properties through multiple history matching solutions. Also included are new insights into the numerical modelling of CO2 injection for enhanced oil recovery in tight oil reservoirs.

JavaScript is disabled for your browser. Some features of this site may not work without it. Developments in modeling and optimization of production in unconventional oil and gas reservoirs. Author Yu, Wei. Metadata Show full item record.

PEH:Tight Gas Reservoirs

Darishchev, A.. Applicability of existing numerical simulation methodologies to unconventional reservoirs is questionable and requires investigation and research. We have focused on gas flow simulation of a highly heterogeneous fractured reservoir with extremely low matrix permeability.

First of all we have considered the key roadmap components, natural gas composition, rock properties, critical elements and the main features inherent in tight and shale gas reservoir engineering. Using field reference data and a reservoir simulator, different scenarios of gas production have been modelled. This paper presents results from a sensitivity study of the dimension of hydraulic fracturing stimulated reservoir volume SRV , matrix and propped fracture permeability which is spatially varied as one of the most realistic approaches, and of the bottom hole pressure.

The approaches "dual porosity -single permeability", "dual porosity -dual permeability" and key reservoir properties have been reconsidered for specific geological and technological conditions in order to support decision making in unconventional reservoir management.

Assuming pseudo-steady state gas flow, the simulation time step and gridblock size have been adjusted with a sector model represented by a logarithmically refined grid. In comparison with previous studies, it has been stated that the proposed approach of discrete fracture network modeling can be used in cases where the dual medium approach is questionable or inappropriate.

The simulations of flow that have been performed, showed that the contribution of unstimulated reservoir volume in the vicinity of the SRV to gas production is non-negligible and can be a significant part of gas production to be taken into account in some field cases. The results of this study can be used in unconventional reservoir modeling and flow simulation to identify development, stimulation, and completion strategies aimed at optimization of gas production, reservoir performance and gas recovery.

The proposed approach also supports risk and uncertainty analysis, revenue estimation and economic performance evaluation. Sign In or Register. Advanced Search. Sign In. Skip Nav Destination Proceeding Navigation.

Close mobile search navigation. All Days. Previous Paper Next Paper. Article Navigation. Darishchev ; A.. This Site. Google Scholar. Lemouzy ; P.. Rouvroy P.. Published: January 28 Abstract Applicability of existing numerical simulation methodologies to unconventional reservoirs is questionable and requires investigation and research.

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Modeling and simulation of gas flow behavior in shale reservoirs

Thank you for visiting nature. You are using a browser version with limited support for CSS. To obtain the best experience, we recommend you use a more up to date browser or turn off compatibility mode in Internet Explorer. In the meantime, to ensure continued support, we are displaying the site without styles and JavaScript. The horizontal wells and multi-stage hydraulic fracturing technologies play a significantly important role in developing unconventional reservoirs. Due to the nanopore effects and stress deformation in tight formations, the fluid equilibrium and thermodynamics become more complex and the conventional reservoir simulation models cannot accurately handle these mechanisms.

Shale is a growing prospect in this world with decreasing conventional sources of fossil fuel. With the growth in demand for natural gas, there is impending need for the development of the robust model for the flow of shale gas Behar and Vandenbroucke in Org Geochem, —24, So the major driving force behind the working on this major project is the unavailability of desired models that could lead to enhanced production of these wells and that too efficiently. This model mainly includes the movement of shale gas from tight reservoir through the conductive fractures to wellbore and production model of the decline in pressure inside the reservoir with respect to time. The result shows the applicability of this in the real-life projects where it is difficult to model the fractures and obtain the flow rate with them in fractures and how to set the production facilities becomes a question. Shale is known as fine-grained, clastic sedimentary rock. The molecule size of shale is little which makes the interstitial spaces likewise little.

The mathematical model of coupled flow and geomechanics for a vertical fractured well in tight gas reservoirs was established. The analytical modeling of unidirectional flow and radial flow was achieved by Laplace transforms and integral transforms. The results show that uncoupled flow would lead to an overestimate in performance of a vertical fractured well, especially in the later stage. The production rate decreases with elastic modulus because porosity and permeability decrease accordingly. Drawdown pressure should be optimized to lower the impact of coupled flow and geomechanics as a result of permeability decreasing. Production rate increases with fracture half-length significantly in the initial stage and becomes stable gradually. This study could provide a theoretical basis for effective development of tight gas reservoirs.

Shale Gas and Tight Oil Reservoir Simulation

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Darishchev, A.. Applicability of existing numerical simulation methodologies to unconventional reservoirs is questionable and requires investigation and research.

Shale Gas and Tight Oil Reservoir Simulation

The organic content often adsorbs some gas content, while the adsorbed amount for different gas species is different. With the proposed model, we study the effect of non-Darcy flow, length of the hydraulic fracture, and initial gas composition on gas production. The results show both non-Darcy flow and fracture length have significant influence on gas production. Gas production increases with fracture length. In lower permeable reservoirs, gas production increases almost linearly with the hydraulic fracture length.

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Shale gas reservoirs have a relatively small permeability, in the range of Via the fluid flow numerical simulation approach, the effects of unconventional resources like tight gas and oil, coalbed methane and shale gas.


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