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By Nick Bahrami

Tight fuel reservoirs have very low permeability and porosity, which can't be produced at low-budget stream charges except the good is successfully inspired and accomplished utilizing complex and optimized applied sciences. inexpensive creation at the foundation of tight gasoline reservoirs is difficult as a rule, not just because of their very low permeability but in addition to numerous diversified types of formation harm that could happen in the course of drilling, crowning glory, stimulation, and creation operations.

This learn demonstrates intimately the results of alternative good and reservoir static and dynamic parameters that impression harm mechanisms and good productiveness in tight gasoline reservoirs. Geomechanics, petrophysics, construction and reservoir engineering services for reservoir characterization is mixed with a reservoir simulation method and middle research experiments to appreciate the optimal technique for tight fuel improvement, providing stronger good productiveness and gasoline recovery.

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Extra info for Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

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9 show the effect of water blocking damage in tight formations with normal Swi. In the case of non-fractured well, water blocking damage causes significant drop in gas production rate, and in the case of a fractured well, the hydraulic fractures could improve well productivity. With 5 hydraulic fractures, the stabilized gas production rate at late time is almost similar in the cases of damaged and non-damaged wells (A3 and A6), which indicates that the dominant effect of large hydraulic fractures compared with formation damage effect.

Water saturation at the end of the gas production period is shown in Fig. 4 (equivalent radius of water invaded zone: 12 ft). The results indicate during the gas production phase, not only water from the near wellbore was not cleaned up by gas production, water invasion was continued into the reservoir due to the strong capillary pressure suction effects, and damaged zone radius (water invaded radius) increased with passage of time. Fig. 4 Water saturation in the model at the end of gas production period X Y 100 ft Sw 100 ft 24 3 Tight Gas Reservoir Simulation Fig.

N X ðKf à bÞ ð2:7Þ fracture h ¼ ðn à aÞ þ ðn à bÞ ð2:8Þ where Kf is permeability of a natural fracture, b is average fracture aperture, a is average matrix block thickness, K is welltest permeability, Km is average permeability of the matrix blocks, h is reservoir thickness, n is number of fractures intersecting the wellbore across the reservoir, uf is fracture porosity (fraction), n * a is cumulative matrix block thickness, and n * b is cumulative fracture aperture. By combining Eqs. 7 using the assumption of a ) b, Kf ) Kwelltest and Kf ) Km for tight gas reservoirs, following simplified equation can be written: a b Kf ¼ Kwelltest à ð2:9Þ Since Eq.

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