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• W2029368248 abstract "SPE Member Abstract During the depletion history of an abnormally pressured reservoir, pressure is initially maintained by a decrease in the pore volume. The P/z vs cumulative gas produced graph in such reservoirs shows two distinct produced graph in such reservoirs shows two distinct slopes and the initial gas in place can be estimated by extrapolation of p/z straight line after the reservoir gradient has been reduced to normal. This decrease in pore volume also results in a reduction in the pore volume also results in a reduction in the effective permeability of the rock thus affecting the formation in-flow performance. In the gas-condensate reservoirs, hydrocarbon liquids drop out of the gas phase below the dewpoint pressures increasing the total liquids saturation. An increase in the liquid saturation decreases the relative permeability to gas. permeability to gas. The paper develops a high pressure gas-condensate reservoir deliverability calculation incorporating the effect of gas permeability reduction due to a decrease in pore volume and increase in oil saturation. Introduction Shape of the P/Z vs cumulative gas produced graph for abnormally pressured reservoirs has been well documented in the literature. Hammerlindl et all derived an initial gas in place correction factor to account for change in the effective total compressibility as a result of decrease in reservoir pressure to normal gradient. This factor is based upon an average ratio of effective compressibility to the gas compressibility before and after the normal gradient. Ramagost et al presented a graphical method to plot a corrected P/Z presented a graphical method to plot a corrected P/Z vs Gp straight line that can be extrapolated to the original gas in place. An increase in overburden pressure in many reservoirs also results in a decrease in permeability of the rock. If the original rock permeability or the initial deliverability tests are used to calculate future well performance without accounting for decrease in performance without accounting for decrease in permeability, the results would be optimistic. The degree of permeability, the results would be optimistic. The degree of error depends upon the ratio of abandonment rock permeability to the original rock permeability. permeability to the original rock permeability. Unconsolidated sandstones with high clay content show the maximum degree of change, while consolidated limestones or dolomites hardly show any decrease in permeability. Another source of error in the projected deliverability calculations is the decrease in relative permeability to gas as a result of liquids dropout in the reservoir. The original effective permeability to gas is valid only as the reservoir and bottomhole flowing pressure is above the dewpoint pressure. As the bottomhole flowing pressure decreases below the dewpoint, there is a liquid dropout around the wellbore. This eventually results in an oil saturation above the critical saturation and start of two-phase flow into the wellbore. The radius of this two-phase flow region depends upon the pressure drop profile in the reservoir. When the reservoir pressure reaches below the dewpoint overall liquids dropout in the reservoir does not usually result in liquid saturations above the critical values. Therefore, the liquid phase in the reservoir as a whole remains immobile. But the relative permeability to gas is now reduced in the reservoir as well as the two-phase region around the wellbore. Calculation of future well performance using the Russell and Goodrich equation and a constant effective permeability to gas would result in optimistic flow permeability to gas would result in optimistic flow rates. For overpressured gas-condensate reservoirs, effective permeability to gas must be used as a variable dependent upon reservoir pressure and liquid saturation to project realistic future well deliverabilities using the Russell and Goodrich equation. Discussion Russell and Goodrich et al deliverability equation for estimating flow rate of a gas well is given as follows: (i) or in the terms of real gas pseudo pressures, the same equation may be written as: (ii) P. 203" @default.
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• W2029368248 date "1985-03-11" @default.
• W2029368248 modified "2023-09-25" @default.
• W2029368248 title "Deliverability Projection Model for Overpressured Gas-Condensate Reservoirs" @default.
• W2029368248 doi "https://doi.org/10.2118/13706-ms" @default.
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